Fortis Inc. ("Fortis" or the "Corporation") (TSX:FTS) recorded second quarter
net earnings applicable to common shares of $29 million, or $0.19 per common
share, compared to earnings of $41 million, or $0.31 per common share, for the
second quarter of 2007. Year-to-date earnings applicable to common shares were
$120 million, or $0.77 per common share, compared to earnings of $83 million, or
$0.69 per common share, for the same period last year. Terasen was acquired on
May 17, 2007 and, consequently, the Corporation's financial results for the
prior period last year reflected earnings' contribution from Terasen for a
partial second quarter.
Second quarter results included a $13 million, or $0.08 per common share, charge
representing the Corporation's approximate 70 per cent share of disallowed
previously incurred fuel and purchased power costs at Belize Electricity. The
charge was the result of the decision by the Public Utilities Commission of
Belize on Belize Electricity's 2008/2009 rate application. Belize Electricity
filed an application for judicial review and appeal of the decision with the
Supreme Court of Belize on July 25, 2008. At the end of the second quarter,
Belize Electricity's assets represented approximately 2 per cent of the total
assets of Fortis.
Second quarter results also included a one-time charge of approximately $2
million at FortisOntario associated with the repayment of interconnection
agreement amounts received in the fourth quarter of 2007.
Excluding the one-time items at Belize Electricity and FortisOntario, earnings
for the second quarter were $44 million, or $0.28 per common share, compared to
$41 million, or $0.31 per common share, for the same quarter last year.
Earnings were favourably impacted by a full quarter of earnings' contribution
from the Terasen Gas companies, higher earnings at Newfoundland Power associated
with a shift in the quarterly distribution of annual purchased power expense,
increased non-regulated hydroelectric production and improved performance at
Fortis Properties. Partially offsetting these items were lower earnings at
FortisAlberta associated with higher corporate income taxes, and higher
corporate financing costs associated with the Terasen acquisition.
"The Terasen Gas companies have contributed earnings of $120 million since
acquisition almost 15 months ago and are now substantially integrated into the
Fortis Group of Companies," says Stan Marshall, President and Chief Executive
Officer, Fortis.
The Terasen Gas companies contributed earnings of $12 million for the second
quarter, up $11 million from the same quarter last year; however, contributions
last year were from May 17, 2007, the date of acquisition. On a full
quarter-over-quarter basis, earnings of the Terasen Gas companies were
comparable. In August 2008, Terasen settled certain historical corporate tax
matters and, as a result, is expected to record an earnings' benefit of
approximately $7.5 million in the third quarter of 2008.
Excluding the one-time item at FortisOntario, Canadian Regulated Electric
Utilities' earnings were $28 million for the second quarter compared to $33
million for the same quarter last year. The decrease in earnings was mainly due
to a $7.5 million increase in future income tax expense at FortisAlberta
associated with regulator-approved deferral accounts and the timing of their
collection. FortisAlberta is expected to record a future income tax recovery
when the deferral accounts are collected. Partially offsetting the above
decrease was the favourable impact of a shift in the quarterly distribution of
annual purchased power expense at Newfoundland Power, which increased earnings
during the second quarter of 2008 by approximately $2.5 million. Newfoundland
Power's annual earnings are not expected to be impacted by the shift in
quarterly earnings' distribution; however, earnings are expected to be lower in
the first and fourth quarters and higher in the second and third quarters
compared to the same periods last year.
Excluding the one-time item at Belize Electricity, Caribbean Regulated Electric
Utilities' earnings were $8 million for the second quarter, comparable to
earnings for the same quarter last year. The favourable impact of electricity
sales growth and a change in the method of calculating fuel costs under
Caribbean Utilities' new transmission and distribution licence was largely
offset by higher operating expenses, increased amortization costs, and the 3.25
per cent reduction in basic electricity rates at Caribbean Utilities, effective
January 1, 2008. Commencing June 1, 2009, Caribbean Utilities will be permitted
to adjust basic electricity rates with a formula tied to inflation.
Year to date, Fortis and its utilities have raised almost $900 million in
preferred equity and 30-year debt including the issuance of $230 million 5.25%
First Preference Shares at Fortis Inc., $250 million 5.80% debentures at Terasen
Gas Inc., $250 million 6.05% debentures at Terasen Gas (Vancouver Island) Inc.,
$100 million 5.85% debentures at FortisAlberta and $60 million 6.05% bonds at
Maritime Electric.
In June 2008, Caribbean Utilities announced a rights offering to shareholders of
record on July 14, 2008. The estimated net proceeds of approximately US$28
million will be used to repay credit facility borrowings and to finance capital
expenditures. The rights offering closes on August 15, 2008.
Non-Regulated Fortis Generation contributed earnings of $7 million for the
second quarter, up $2 million from the same quarter last year. Results
reflected increased hydroelectric production in central Newfoundland due to
higher rainfall.
Fortis Properties contributed earnings of $7 million for the second quarter, up
$1 million from the same quarter in 2007. The increase reflected contributions
from the Delta Regina in Saskatchewan, acquired on August 1, 2007, and improved
performance at the Company's hospitality operations in Atlantic Canada.
Corporate and other expenses were $18 million for the second quarter compared to
$12 million for the same quarter last year. The increase in corporate and other
expenses was primarily driven by a full quarter of Terasen acquisition-related
finance charges compared to a partial quarter last year.
Cash flow from operating activities was $244 million in the second quarter of
2008, up from $68 million in the same quarter last year. Cash flow from
operating activities was $432 million year to date, up from $162 million in the
same period last year. The improvement reflected seasonality of operations of
the Terasen Gas companies and their contribution for all of the second quarter
and year-to-date period in 2008 compared to a partial second quarter last year.
Consolidated capital expenditures, before customer contributions, were $389
million in the first half of 2008 and are expected to exceed $900 million for
the year. Much of the consolidated capital program is being driven by the
Terasen Gas companies, FortisAlberta, FortisBC, and regulated and non-regulated
electric utility operations in the Caribbean. During the quarter, Terasen Gas
(Vancouver Island) Inc. commenced construction of its $200 million liquefied
natural gas storage facility.
"Fortis is a leading energy infrastructure builder in Canada. The Corporation's
consolidated capital expenditure program is expected to exceed $4.5 billion over
the next five years which should drive earnings growth going forward," concludes
Mr. Marshall.
Interim Management Discussion and Analysis
For the three and six months ended June 30, 2008
Dated August 8, 2008
The following analysis should be read in conjunction with the Fortis Inc.
("Fortis" or the "Corporation") interim unaudited consolidated financial
statements and notes thereto for the three and six months ended June 30, 2008
and the Management Discussion and Analysis ("MD&A") and audited consolidated
financial statements for the year ended December 31, 2007 included in the
Corporation's 2007 Annual Report. This material has been prepared in accordance
with National Instrument 51-102 - Continuous Disclosure Obligations relating to
MD&As. Financial information in this release has been prepared in accordance
with Canadian generally accepted accounting principles ("Canadian GAAP") and is
presented in Canadian dollars unless otherwise specified.
Fortis includes forward-looking information in the MD&A within the meaning of
applicable securities laws in Canada ("forward-looking information"). The
purpose of the forward-looking information is to provide management's
expectations regarding the Corporation's future growth, results of operations,
performance, business prospects and opportunities and may not be appropriate for
other purposes. All forward-looking information is given pursuant to the "safe
harbour" provisions of applicable Canadian securities legislation. The words
"anticipates", "believes", "could", "estimates", "expects", "forecasts",
"intends", "may", "might", "plans", "projects", "schedule", "should", "will",
"would" and similar expressions are often intended to identify forward-looking
information, although not all forward-looking information contains these
identifying words. The forward-looking information reflects management's
current beliefs and is based on information currently available to the
Corporation's management. The forward-looking information in the MD&A includes,
but is not limited to, statements regarding: that cash required to complete the
consolidated capital expenditure program and to finance acquisitions is expected
to be derived from a combination of borrowings under credit facilities and the
issuance of common shares, preference shares and long-term debt; the belief of
the Corporation and its subsidiaries that they do not anticipate any
difficulties in accessing required capital on reasonable market terms; the
Corporation's consolidated forecasted gross capital expenditures for 2008 and in
total over the next five years and the Corporation's belief that its capital
program should drive growth in earnings. The forecasts and projections that
make up the forward-looking information are based on assumptions which include,
but are not limited to: the receipt of applicable regulatory approvals and
requested rate orders; no significant operational disruptions or environmental
liability due to a catastrophic event or environmental upset caused by severe
weather, other acts of nature or other major events; the Corporation's ability
to maintain its gas and electricity systems to ensure their continued
performance; the competitiveness of natural gas pricing when compared with
electricity and other alternative sources of energy; the availability of natural
gas supply; favourable economic conditions; the level of interest rates; the
ability to hedge certain risks; access to capital; maintenance of adequate
insurance coverage; the ability to obtain licences and permits; the level of
energy prices; retention of existing service areas; favourable labour relations;
and sufficient human resources to deliver service and execute the capital
program. The forward-looking information is subject to risks, uncertainties and
other factors that could cause actual results to differ materially from
historical results or results anticipated by the forward-looking information.
The factors which could cause results or events to differ from current
expectations include, but are not limited to: regulation; operating and
maintenance risks; natural gas prices and supply; economic conditions; weather
and seasonality; interest rates; changes in tax legislation; derivative
financial instruments and hedging; risks related to Terasen Gas (Vancouver
Island) Inc.; capital resources; environment; insurance; licences and permits;
energy prices and the cessation of the Niagara Exchange Agreement; loss of
service area; First Nations Lands; counterparty risk; labour relations; human
resources; and liquidity risk. For additional information with respect to the
Corporation's risk factors, reference should be made to the Corporation's
continuous disclosure materials filed from time to time with Canadian securities
regulatory authorities and to the heading "Business Risk Management" in the MD&A
for the three and six months ended June 30, 2008 and for the year ended December
31, 2007.
All forward-looking information in the MD&A is qualified in its entirety by the
above cautionary statements and, except as required by law, the Corporation
undertakes no obligation to revise or update any forward-looking information as
a result of new information, future events or otherwise after the date hereof.
COMPANY OVERVIEW AND FINANCIAL HIGHLIGHTS
Fortis is the largest investor-owned distribution utility in Canada serving
almost 2,000,000 gas and electricity customers. Its regulated holdings include
a natural gas utility in British Columbia and electric utilities in five
Canadian provinces and three Caribbean countries. Fortis owns non-regulated
generation assets across Canada and in Belize and Upper New York State, and
hotels and commercial real estate in Canada. In 2007, the Corporation's
electricity distribution systems met a combined peak electricity demand of
approximately 5,700 megawatts ("MW") and its gas distribution systems met a peak
day demand of 1,360 terajoules ("TJ"). For additional information on the
Corporation's business segments, refer to Note 1 to the Corporation's interim
unaudited consolidated financial statements for the three and six months ended
June 30, 2008.
The key goals of the Corporation's regulated utilities are to operate sound gas
and electricity distribution systems, deliver gas and electricity safely and
reliably to customers at reasonable rates, and conduct business in an
environmentally responsible manner. The Corporation's core utility business is
highly regulated. It is segmented by franchise area and, depending on
regulatory requirements, by the nature of the assets.
Fortis has adopted a strategy of profitable growth with earnings per common
share as the primary measure of performance. Key financial highlights,
including earnings by reportable segment, for the second quarter and
year-to-date periods ended June 30, 2008 and June 30, 2007, are provided in the
table below.
--------------------------------------------------------------------------
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
($ millions, except
earnings per
common share and
common shares
outstanding) 2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Revenue 848 566 282 1,994 1,049 945
--------------------------------------------------------------------------
Cash flow from
operating
activities 244 68 176 432 162 270
--------------------------------------------------------------------------
Net earnings
applicable to
common shares 29 41 (12) 120 83 37
--------------------------------------------------------------------------
Basic earnings per
common share ($) 0.19 0.31 (0.12) 0.77 0.69 0.08
--------------------------------------------------------------------------
Diluted earnings per
common share ($) 0.18 0.27 (0.09) 0.75 0.61 0.14
--------------------------------------------------------------------------
Weighted average
number of common
shares outstanding
(millions) 157.0 131.1 25.9 156.8 120.2 36.6
--------------------------------------------------------------------------
Segmented Net Earnings
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Regulated Gas
Utilities -
Canadian
Terasen Gas
Companies (1) 12 1 11 70 1 69
--------------------------------------------------------------------------
Regulated Electric
Utilities -
Canadian
--------------------------------------------------------------------------
FortisAlberta 7 15 (8) 18 27 (9)
--------------------------------------------------------------------------
FortisBC (2) 7 6 1 19 18 1
--------------------------------------------------------------------------
Newfoundland Power 10 8 2 16 19 (3)
--------------------------------------------------------------------------
Other Canadian (3) 2 4 (2) 6 8 (2)
--------------------------------------------------------------------------
26 33 (7) 59 72 (13)
--------------------------------------------------------------------------
Regulated Electric
Utilities -
Caribbean (4) (5) 8 (13) 2 12 (10)
--------------------------------------------------------------------------
Non-Regulated -
Fortis Generation (5) 7 5 2 13 12 1
--------------------------------------------------------------------------
Non-Regulated -
Fortis Properties (6) 7 6 1 10 8 2
--------------------------------------------------------------------------
Corporate and
other (7) (18) (12) (6) (34) (22) (12)
--------------------------------------------------------------------------
Net Earnings
Applicable to
Common Shares 29 41 (12) 120 83 37
--------------------------------------------------------------------------
(1) Comprised of Terasen Gas Inc. ("TGI"), Terasen Gas (Vancouver Island)
Inc. ("TGVI") and Terasen Gas (Whistler) Inc. ("TGWI"). Financial
results are reported from May 17, 2007, the date of acquisition.
(2) Includes the regulated operations of FortisBC Inc. and operating,
maintenance and management services related to the Waneta, Brilliant
and Arrow Lakes hydroelectric generating plants and the distribution
system owned by the City of Kelowna. Excludes the non-regulated
generation operations of FortisBC Inc.'s wholly owned partnership,
Walden Power Partnership.
(3) Includes Maritime Electric and FortisOntario. FortisOntario includes
Canadian Niagara Power and Cornwall Electric.
(4) Includes Belize Electricity, in which Fortis holds an approximate 70
per cent controlling interest; Caribbean Utilities on Grand Cayman,
Cayman Islands, in which Fortis holds an approximate 54 per cent
controlling interest; and wholly owned Fortis Turks and Caicos.
Caribbean Utilities has an April 30 fiscal year end; therefore,
Caribbean Utilities' financial statements are consolidated in the
financial statements of Fortis on a two-month lag basis.
(5) Includes the operations of non-regulated generation assets in Belize,
Ontario, central Newfoundland, British Columbia and Upper New York
State, with a combined generating capacity of 195 MW, mainly
hydroelectric.
(6) Includes 19 hotels with more than 3,500 rooms in eight Canadian
provinces and approximately 2.8 million square feet of commercial real
estate primarily in Atlantic Canada.
(7) Includes Fortis net corporate expenses and, from May 17, 2007, the net
expenses of non-regulated Terasen Inc. ("Terasen") corporate-related
activities and the financial results of Terasen's 30 per cent ownership
interest in CustomerWorks Limited Partnership ("CWLP") and of Terasen's
non-regulated wholly owned subsidiary Terasen Energy Services Inc.
("TES").
--------------------------------------------------------------------------
SEGMENTED RESULTS OF OPERATIONS
REGULATED GAS UTILITIES - CANADIAN
Terasen Gas Companies
--------------------------------------------------------------------------
Terasen Gas Companies (1)
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Gas Volumes (TJ) 45,324 17,744 27,580 123,508 17,744 105,764
--------------------------------------------------------------------------
($ millions)
--------------------------------------------------------------------------
Revenue 390 130 260 1,025 130 895
--------------------------------------------------------------------------
Energy Supply Costs 256 73 183 693 73 620
--------------------------------------------------------------------------
Operating Expenses 62 28 34 123 28 95
--------------------------------------------------------------------------
Amortization 25 12 13 49 12 37
--------------------------------------------------------------------------
Finance Charges 30 15 15 63 15 48
--------------------------------------------------------------------------
Corporate Taxes 5 1 4 27 1 26
--------------------------------------------------------------------------
Earnings 12 1 11 70 1 69
--------------------------------------------------------------------------
(1) Financial results are reported from May 17, 2007, the date of
acquisition.
--------------------------------------------------------------------------
On May 17, 2007, Fortis acquired all of the issued and outstanding common shares
of Terasen. Terasen owns and operates a gas distribution business carried on by
TGI, TGVI and TGWI, collectively referred to as the Terasen Gas companies, and
is the principal distributor of natural gas in British Columbia.
Gas volumes: Gas volumes at the Terasen Gas companies were 45,324 TJ during the
second quarter of 2008, up 846 TJ, or 1.9 per cent, from 44,478 TJ reported by
the Terasen Gas companies for the full quarter last year. Gas volumes year to
date were 123,508 TJ, up 3,080 TJ, or 2.6 per cent, from 120,428 TJ reported by
the Terasen Gas companies for the full year-to-date period last year. The
increases were driven by higher consumption due to cooler weather compared to
the same periods last year.
Changes in consumption levels and energy supply costs from those forecasted to
set gas distribution rates, do not materially impact earnings as a result of the
operation of British Columbia Utilities Commission ("BCUC")-approved regulatory
deferral mechanisms.
During the second quarter of 2008, net customer additions at TGI and TGVI
totalled 845, bringing the total customer count to approximately 921,970 at June
30, 2008. Year-to-date 2008, net customer additions totalled 3,339, lower than
net customer additions of 4,199 during the same period last year but in line
with expectations. Favourable economic conditions and housing activity in
British Columbia continue to positively impact customer growth in the region.
Revenue: The Terasen Gas companies contributed a full quarter and half year of
revenue of approximately $390 million and $1.0 billion, respectively, compared
to revenue of $130 million for a partial second quarter last year. Factors
favourably impacting revenue during the second quarter and year-to-date period
of 2008 included: (i) increased customer consumption due to cooler weather; (ii)
higher gas commodity costs charged to customers; and (iii) an increase in gas
distribution rates, effective January 1, 2008, associated with an increase in
the 2008 allowed rates of return on common shareholders' equity ("ROE") for TGI
and TGVI to 8.62 per cent and 9.32 per cent, respectively, from 8.37 per cent
and 9.07 per cent, respectively.
Earnings: The Terasen Gas companies contributed a full quarter and half year of
earnings of $12 million and $70 million, respectively, compared to earnings of
$1 million for a partial second quarter last year. Seasonality materially
impacts the earnings of the Terasen Gas companies as a major portion of the gas
distributed is used for space heating. Virtually all of the annual earnings of
the Terasen Gas companies occur in the first and fourth quarters. The
significant factors favourably impacting earnings during the second quarter and
year-to-date period of 2008 included the increase in the allowed ROEs, effective
January 1, 2008, and lower effective corporate taxes, partially offset by
increased amortization costs associated with continued investment in capital
assets, and higher finance charges reflective of higher borrowing rates and
increased credit facility borrowings.
For a discussion of the nature of regulation and material regulatory decisions
and applications pertaining to the Terasen Gas companies, refer to "Regulatory
Highlights".
REGULATED ELECTRIC UTILITIES - CANADIAN
FortisAlberta
--------------------------------------------------------------------------
FortisAlberta
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Energy Deliveries
(GWh) 3,768 3,650 118 7,906 7,595 311
--------------------------------------------------------------------------
($ millions)
--------------------------------------------------------------------------
Revenue 75 68 7 148 132 16
--------------------------------------------------------------------------
Operating Expenses 32 30 2 65 59 6
--------------------------------------------------------------------------
Amortization 21 19 2 41 37 4
--------------------------------------------------------------------------
Finance Charges 11 9 2 20 18 2
--------------------------------------------------------------------------
Corporate Tax
Expense (Recovery) 4 (5) 9 4 (9) 13
--------------------------------------------------------------------------
Earnings 7 15 (8) 18 27 (9)
--------------------------------------------------------------------------
Energy Deliveries: Energy deliveries at FortisAlberta increased 118 gigawatt
hours ("GWh"), or 3.2 per cent, quarter over quarter and increased 311 GWh, or
4.1 per cent, year to date compared to the same period last year. The increases
were due to increased energy demand attributable to customer growth. The number
of customers at FortisAlberta increased by 5,500 to approximately 453,500 during
the first half of 2008.
Revenue: Revenue was $7 million higher quarter over quarter and $16 million
higher year to date compared to the same period last year. The increases were
mainly due to customer growth; a 6.8 per cent increase in customer distribution
rates, effective January 1, 2008; and the accrual of the impact for collection
in future customer distribution rates of the increase in the 2008 allowed ROE to
8.75 per cent from 8.51 per cent, effective January 1, 2008.
Earnings: FortisAlberta's earnings were $8 million lower quarter over quarter,
driven by increased corporate taxes, primarily associated with the
regulator-approved Alberta Electric System Operator ("AESO") charges deferral
account and the timing of its collection. Quarter over quarter, the impact of
customer growth, the increase in customer distribution rates and a higher
allowed ROE was partially offset by: (i) higher operating expenses due to
increased contracted manpower costs, higher labour and employee-benefit costs
associated with increased salaries and number of employees, partially offset by
lower general operating expenses; (ii) increased amortization costs associated
with continued investment in capital assets and higher amortization rates
provided for in the 2008/2009 Negotiated Settlement Agreement ("NSA"); and (iii)
increased finance charges due to higher debt levels in support of the Company's
significant capital expenditure program.
Earnings were $9 million lower year to date compared to the same period last
year mainly as a result of increased corporate taxes for the reasons described
above for the quarter. Additionally, the impact of (i) higher operating
expenses due to increased contracted manpower costs, higher labour and
employee-benefit costs associated with increased salaries and number of
employees, and higher general operating expenses; and (ii) increased
amortization costs and finance charges for the reasons described above for the
quarter was more than offset by the impact of customer growth, the increase in
customer distribution rates and a higher allowed ROE.
FortisAlberta collects from customers and records income taxes on the cash taxes
payable method, as approved by its regulator, except for certain
regulator-approved deferral accounts whereby income taxes are recorded on the
liability method. FortisAlberta does not expect to incur any cash income taxes
in 2008. For the second quarter and year-to-date period of 2008, the future
corporate income tax expense of $4 million was primarily associated with an
increase in the balance of deferred AESO charges. However, for the second
quarter and year-to-date period of 2007, a recovery of future income tax expense
of $3.5 million and $7 million, respectively, was recorded primarily due to a
reduction in the balance of deferred AESO charges. FortisAlberta's AESO charges
deferral account captures variances between amounts charged by the AESO to
FortisAlberta for transmission tariffs and amounts collected from
FortisAlberta's customers through the transmission tariff component of basic
customer rates. Subject to regulatory approval, amounts charged by the AESO in
excess of amounts collected from customers are deferred as a regulatory asset
for future recovery from customers and amounts collected from customers in
excess of amounts charged are deferred as a regulatory liability for future
refund to customers.
Generally, there is a two-year regulatory lag between the deferral of amounts in
the AESO charges deferral account and when they are collected from, or refunded
to, customers in rates. In 2007, the 2005 deferred AESO charges receivable
balance was collected in customer rates. Additionally, FortisAlberta received
regulatory approval to sell amounts in its annual AESO charges deferral account.
In September 2007 and December 2007, the 2006 deferred AESO charges receivable
balance of $28 million and approximately $37 million of the 2007 deferred AESO
charges receivable balance, respectively, were sold to a Canadian chartered bank
and, as a result, the proceeds were recognized in 2007. To date, FortisAlberta
has not entered into any transaction to sell its 2008 deferred AESO charges
receivable balance.
For a discussion of the nature of regulation and material regulatory decisions
and applications pertaining to FortisAlberta, refer to "Regulatory Highlights".
FortisBC
--------------------------------------------------------------------------
FortisBC
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Electricity Sales
(GWh) 673 670 3 1,548 1,549 (1)
--------------------------------------------------------------------------
($ millions)
--------------------------------------------------------------------------
Revenue 53 52 1 119 115 4
--------------------------------------------------------------------------
Energy Supply Costs 12 13 (1) 33 33 -
--------------------------------------------------------------------------
Operating Expenses 17 17 - 33 33 -
--------------------------------------------------------------------------
Amortization 8 8 - 17 16 1
--------------------------------------------------------------------------
Finance Charges 7 6 1 14 12 2
--------------------------------------------------------------------------
Corporate Taxes 2 2 - 3 3 -
--------------------------------------------------------------------------
Earnings 7 6 1 19 18 1
--------------------------------------------------------------------------
Electricity Sales: Electricity sales at FortisBC were comparable quarter over
quarter and year to date compared to the same period last year. Electricity
sales during the first half of 2008 were impacted by reduced industrial customer
loads, as a result of a general slowdown in the forestry sector, largely offset
by residential, general service and wholesale customer growth primarily in the
Okanagan region.
Revenue: Revenue was $1 million higher quarter over quarter and $4 million
higher year to date compared to the same period last year. Revenue increased
mainly due to: (i) a 2.9 per cent increase in customer rates, effective January
1, 2008, which included the impact of an increase in the 2008 allowed ROE to
9.02 per cent from 8.77 per cent; and (ii) a 0.8 per cent increase in customer
rates, effective May 1, 2008, as a result of the flow through to customers of
increased purchased power costs from BC Hydro. The increase was partially
offset by lower revenue contributions from non-regulated operating, maintenance
and management services.
Earnings: FortisBC's earnings were $1 million higher quarter over quarter. The
impact of the 2.9 per cent increase in electricity rates and decreased energy
supply costs, driven by lower average power purchase prices and the receipt of
$0.6 million of insurance proceeds associated with a turbine generator failure
in 2006, was partially offset by higher finance charges, reflective of the
Company's significant capital expenditure program.
Earnings were $1 million higher year to date compared to the same period last
year. The impact of the 2.9 per cent increase in electricity rates was
partially offset by higher amortization costs and finance charges reflective of
the Company's significant capital expenditure program.
Operating expenses were comparable quarter over quarter and year to date
compared to the same period last year. The impact of the timing in 2008 of
certain operating and maintenance projects combined with higher labour costs and
general inflationary increases was largely offset by lower operating expenses
associated with non-regulated operating maintenance and management services.
Energy supply costs year to date were comparable to the same period last year.
A higher proportion of energy generated from Company-owned hydroelectric
generating plants versus power purchased period over period, combined with the
receipt of insurance proceeds and lower electricity sales, were offset by higher
average power purchase prices.
For a discussion of the nature of regulation and material regulatory decisions
and applications pertaining to FortisBC, refer to "Regulatory Highlights".
Newfoundland Power
--------------------------------------------------------------------------
Newfoundland Power
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Electricity Sales
(GWh) 1,183 1,172 11 2,899 2,835 64
--------------------------------------------------------------------------
($ millions)
--------------------------------------------------------------------------
Revenue 120 115 5 284 269 15
--------------------------------------------------------------------------
Energy Supply Costs 70 74 (4) 192 180 12
--------------------------------------------------------------------------
Operating Expenses 13 13 - 27 27 -
--------------------------------------------------------------------------
Amortization 12 9 3 22 19 3
--------------------------------------------------------------------------
Finance Charges 9 8 1 17 16 1
--------------------------------------------------------------------------
Corporate Taxes 6 3 3 10 8 2
--------------------------------------------------------------------------
Earnings 10 8 2 16 19 (3)
--------------------------------------------------------------------------
Electricity Sales: Electricity sales at Newfoundland Power increased 11 GWh
quarter over quarter, driven by customer growth, partially offset by lower
average consumption. Electricity sales increased 64 GWh, or 2.3 per cent, year
to date compared to the same period last year, largely due to the combined
impact of customer growth and higher average consumption.
Revenue: Revenue was $5 million higher quarter over quarter and $15 million
higher year to date compared to the same period last year. The increases were
driven by electricity sales growth and an average increase in customer rates of
2.8 per cent, effective January 1, 2008, which included the impact of an
increase in the 2008 allowed ROE to 8.95 per cent from 8.60 per cent. The
increase in revenue also reflected higher amortization of regulatory liabilities
in accordance with prescribed regulatory orders.
Earnings: Newfoundland Power's earnings were $2 million higher quarter over
quarter, reflecting a quarterly shift in the distribution of annual purchased
power expense which increased earnings by approximately $2.5 million during the
second quarter of 2008. Under the regulated rate structure, annual purchased
power expense per kilowatt hour ("kWh") is higher in the winter months and lower
in the summer months. During 2007, Newfoundland Power estimated and recognized
monthly purchased power expense based on forecast annual average cost per kWh.
Differences between the estimated monthly purchased power expense and that based
on the actual cost per kWh were adjusted to a regulatory reserve that was
discontinued for use effective January 1, 2008. Monthly purchased power expense
is now being recorded at actual cost per kWh. As a result of this change,
earnings in 2008 are expected to be lower in the first and fourth quarters and
higher in the second and third quarters compared to the same periods in 2007.
Annual earnings will not be impacted by the shift in quarterly earnings.
Excluding the $2.5 million favourable shift in quarterly earnings, as described
above, earnings were $7.5 million for the quarter, slightly lower than $8
million for the same quarter last year. Timing differences related to operating
expenses and the rebasing of customer rates were partially offset by the 2.8 per
cent increase in customer rates.
Newfoundland Power's earnings were $3 million lower year to date compared to the
same period last year, reflecting the quarterly shift in the distribution of
annual purchased power expense which decreased year-to-date earnings by
approximately $3.5 million. Excluding the $3.5 million unfavourable shift in
earnings, year-to-date earnings were approximately $19.5 million, slightly
higher than $19 million for the same period last year. The increase was mainly
the result of the 2.8 per cent increase in customer rates along with related
timing differences associated with the rebasing of customer rates, and increased
electricity sales, partially offset by timing differences related to operating
expenses.
Amortization costs are allocated quarterly based on gross margin. Amortization
costs have increased during 2008 reflecting the regulator-approved recovery of
previously deferred amortization costs in customer rates, effective January 1,
2008. Higher effective corporate income tax rates quarter over quarter and year
to date compared to the same period last year were driven by decreased
deductions taken for tax purposes compared to accounting purposes.
For a discussion of the nature of regulation and material regulatory decisions
and applications pertaining to Newfoundland Power, refer to "Regulatory
Highlights".
Other Canadian Electric Utilities
--------------------------------------------------------------------------
Other Canadian Electric Utilities (1)
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Electricity Sales
(GWh) 508 516 (8) 1,107 1,118 (11)
--------------------------------------------------------------------------
($ millions)
--------------------------------------------------------------------------
Revenue 61 65 (4) 131 135 (4)
--------------------------------------------------------------------------
Energy Supply Costs 40 43 (3) 89 91 (2)
--------------------------------------------------------------------------
Operating Expenses 7 7 - 14 14 -
--------------------------------------------------------------------------
Amortization 5 4 1 9 8 1
--------------------------------------------------------------------------
Finance Charges 5 5 - 9 9 -
--------------------------------------------------------------------------
Corporate Taxes 2 2 - 4 5 (1)
--------------------------------------------------------------------------
Earnings 2 4 (2) 6 8 (2)
--------------------------------------------------------------------------
(1) Includes Maritime Electric and FortisOntario
--------------------------------------------------------------------------
Electricity Sales: Electricity sales at Other Canadian Electric Utilities
decreased 8 GWh, or 1.6 per cent, quarter over quarter, and decreased 11 GWh, or
1.0 per cent, year to date compared to the same period last year, driven by
lower average consumption, in part due to warmer-than-normal weather conditions,
the impact of a temporary shutdown of operations of an industrial customer in
Ontario and an unscheduled maintenance outage by a large customer at Maritime
Electric.
Revenue: Revenue was $4 million lower quarter over quarter and year to date
compared to the same period last year. Revenue decreased approximately $3
million associated with the repayment, during the second quarter of 2008, of a
refund FortisOntario had received during the fourth quarter of 2007. In April
2008, the US Federal Energy Regulatory Commission ("FERC") issued an order
stating that the one-time refund of approximately $3 million ($2 million
after-tax) received by FortisOntario in December 2007 from Niagara Mohawk Power
Corporation ("NIMO"), associated with cross-border transmission interconnection
agreements, should not have been originally ordered as FERC does not have
jurisdiction over the interconnection agreements in question and, therefore, did
not have jurisdiction to order the refund. In May 2008, FortisOntario repaid
the refunded amounts to NIMO.
Revenue was also lower due to a decrease in customer rates at FortisOntario
associated with the flow through to customers of lower energy supply costs in
addition to lower electricity sales. The decrease was partially offset by the
impact of an average 1.1 per cent increase in basic electricity distribution
rates at FortisOntario, effective May 1, 2008, and a 1.8 per cent increase in
basic electricity rates at Maritime Electric, effective April 1, 2008.
Earnings: Earnings were $2 million lower quarter over quarter and year to date
compared to the same period last year. Excluding the one-time $2 million
after-tax repayment by FortisOntario of the refund described above, earnings
were comparable, reflecting stable operating conditions.
In August 2008, FortisOntario and Grimsby Power Inc. entered into a non-binding
letter of intent for the acquisition by FortisOntario of a 10 per cent minority
interest in Grimsby Power Inc.'s electricity distribution business for a cash
payment of approximately $1.1 million plus the provision of services to migrate
Grimsby Power Inc.'s customer information system to FortisOntario's SAP-based
system. Grimsby Power Inc. serves approximately 10,000 customers in a service
territory that is in close proximity to FortisOntario's operations in Fort Erie.
The transaction is structured to take advantage of the existing transfer tax
holiday which expires in October 2008. The transaction is subject to the
completion of due diligence, negotiation, board approval, signing of definitive
documentation and receipt of regulatory approvals.
For a discussion of the nature of regulation and material regulatory decisions
and applications pertaining to Maritime Electric and FortisOntario, refer to
"Regulatory Highlights".
REGULATED ELECTRIC UTILITIES - CARIBBEAN
--------------------------------------------------------------------------
Regulated Electric Utilities - Caribbean (1)
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Average US:CDN
Exchange Rate (2) 1.01 1.10 (0.09) 1.01 1.13 (0.12)
--------------------------------------------------------------------------
Electricity Sales
(GWh) 276 258 18 534 499 35
--------------------------------------------------------------------------
($ millions)
--------------------------------------------------------------------------
Revenue 78 74 4 153 151 2
--------------------------------------------------------------------------
Energy Supply Costs 64 (3) 41 23 104 (3) 85 19
--------------------------------------------------------------------------
Operating Expenses 12 11 1 23 28 (4) (5)
--------------------------------------------------------------------------
Amortization 8 7 1 15 14 1
--------------------------------------------------------------------------
Finance Charges 2 3 (1) 7 7 -
--------------------------------------------------------------------------
Corporate Taxes (1) 1 (2) - 1 (1)
--------------------------------------------------------------------------
Non-Controlling
Interest (2) 3 (5) 2 4 (2)
--------------------------------------------------------------------------
(Loss) Earnings (5) 8 (13) 2 12 (10)
--------------------------------------------------------------------------
(1) Includes Belize Electricity, Caribbean Utilities and Fortis Turks and
Caicos
(2) The reporting currency of Belize Electricity is the Belizean dollar
which is pegged to the US dollar at BZ$2.00 equals US$1.00. The
reporting currency of Caribbean Utilities and Fortis Turks and Caicos
is the US dollar. The Cayman Islands dollar is pegged to the US dollar
at CI$1.00 equals US$1.20.
(3) Energy supply costs during the second quarter of 2008 included an $18
million (BZ$36 million) charge as a result of a regulatory rate
decision by the Public Utilities Commission ("PUC") in Belize in June
2008.
(4) Operating expenses during the first quarter of 2007 included a $4.4
million (US$3.7 million) charge on the disposal of steam-turbine assets
at Caribbean Utilities.
--------------------------------------------------------------------------
Electricity Sales: Regulated Electric Utilities - Caribbean electricity sales
increased 18 GWh, or 7 per cent, quarter over quarter and increased 35 GWh, or
7.0 per cent, year to date compared to the same period last year. The increases
were primarily due to higher demand driven by customer growth. Electricity
sales growth is expected to remain strong throughout the second half of 2008.
Caribbean Utilities expects sales growth for its fiscal year ended April 30,
2009 to be approximately 5 per cent, slightly lower than sales growth
experienced during its previous fiscal year, reflecting the impact of slowing
construction trends and the expected impact on tourism of the current downturn
being experienced in the U.S. economy.
Revenue: Revenue increased $4 million quarter over quarter and increased $2
million year to date compared to the same period last year. Excluding the
unfavourable impact of foreign exchange during the second quarter and year to
date period, associated with the translation of foreign currency-denominated
revenue due to the strengthening of the Canadian dollar against the US dollar
compared to the same periods last year, revenue increased $11 million quarter
over quarter and increased $21 million year to date compared to the same period
last year.
Excluding foreign exchange impacts, factors increasing revenue were strong
electricity sales growth, the full flow through of higher fuel and oil costs to
customers at Caribbean Utilities under the terms of the Company's new
transmission and distribution ("T&D") licence, and the flow through of higher
fuel and oil costs at Fortis Turks and Caicos. Partially offsetting the above
factors was a 3.25 per cent reduction in basic customer rates and the
elimination of the hurricane cost recovery surcharge ("CRS") at Caribbean
Utilities, effective January 1, 2008, under the terms of the Company's new T&D
licence.
Earnings: Earnings' contribution was $13 million lower quarter over quarter.
However, second quarter 2008 earnings were reduced by $13 million, representing
the Corporation's approximate 70 per cent share of $18 million of disallowed
previously incurred fuel and purchased power costs at Belize Electricity. The
$18 million (BZ$36 million) charge was the result of the PUC's decision on
Belize Electricity's 2008/2009 rate application. Excluding the $13 million
charge, earnings' contribution was $8 million for the second quarter of 2008,
comparable to the same quarter last year.
Earnings' contribution was $10 million lower year to date compared to the same
period last year. Earnings' contribution year-to-date last year was reduced by
approximately $2 million as a result of a charge on the disposal of
steam-turbine assets at Caribbean Utilities. Excluding the above item and the
$13 million charge associated with Belize Electricity, earnings' contribution
increased $1 million year to date compared to the same period last year.
Excluding the one-time items in 2008 and 2007 described above and the
unfavourable impact of foreign exchange, electricity sales growth and the
favourable impact on energy supply costs associated with the movement in
deferred fuel costs at Caribbean Utilities were largely offset by higher
operating expenses, increased amortization costs, and the 3.25 per cent
reduction in basic electricity rates at Caribbean Utilities. The movement in
deferred fuel costs was the result of a change in the basis for calculating
those costs under Caribbean Utilities' new T&D licence. Excluding the impact of
foreign exchange, operating costs increased mainly due to increased activity
associated with a high-growth environment, the timing of maintenance activities
and increased provisions for bad debts. Amortization costs increased as a
result of continued investment in capital assets.
In April 2008, Caribbean Utilities and the Government of the Cayman Islands
entered into a new exclusive 20-year T&D licence and a new non-exclusive
21.5-year generation licence. Under the new T&D licence, customer rates will be
set using an initial targeted rate of return on rate base assets ("ROA") of 10
per cent, down from 15 per cent as allowed under the previous licence.
Following the receipt of the new licences, Standard & Poor's ("S&P") affirmed
its 'A' credit ratings on Caribbean Utilities' long-term corporate credit and
senior unsecured debt and removed the ratings from credit watch.
In June 2008, Caribbean Utilities announced a rights offering to shareholders of
record on July 14, 2008. The estimated net proceeds of approximately US$28
million will be used to repay credit facility borrowings and to finance capital
expenditures. The rights offering closes on August 15, 2008.
For additional information on the impact of the new licences and the nature of
regulation and material regulatory decisions and applications pertaining to
Belize Electricity, Caribbean Utilities and Fortis Turks and Caicos, refer to
"Regulatory Highlights".
NON-REGULATED - FORTIS GENERATION
--------------------------------------------------------------------------
Non-Regulated - Fortis Generation (1)
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Energy Sales (GWh) 312 274 38 600 565 35
--------------------------------------------------------------------------
($ millions)
--------------------------------------------------------------------------
Revenue 22 18 4 41 39 2
--------------------------------------------------------------------------
Energy Supply Costs 2 2 - 4 4 -
--------------------------------------------------------------------------
Operating Expenses 4 4 - 8 8 -
--------------------------------------------------------------------------
Amortization 3 2 1 5 5 -
--------------------------------------------------------------------------
Finance Charges 2 2 - 4 5 (1)
--------------------------------------------------------------------------
Corporate Taxes 2 2 - 5 4 1
--------------------------------------------------------------------------
Non-Controlling
Interest 2 1 1 2 1 1
--------------------------------------------------------------------------
Earnings 7 5 2 13 12 1
--------------------------------------------------------------------------
(1) Includes the operations of non-regulated generation assets in Belize,
Ontario, central Newfoundland, British Columbia and Upper New York State.
--------------------------------------------------------------------------
Energy Sales: Energy sales from Non-Regulated - Fortis Generation increased 38
GWh, or 13.9 per cent, quarter over quarter and increased 35 GWh, or 6.2 per
cent, year to date compared to the same period last year. The increases were
mainly due to higher production in central Newfoundland during the second
quarter of 2008 as a result of higher rainfall. At the end of July 2008, the
reservoir at the Corporation's generating facility in central Newfoundland was
at approximately two-thirds of its maximum energy supply level while the
Chalillo reservoir in Belize was at its full supply level.
Revenue: Revenue was $4 million higher quarter over quarter. Factors increasing
revenue were: (i) higher production; (ii) increased average wholesale energy
prices per megawatt hour ("MWh") in Ontario of $46.86 during the second quarter
of 2008 compared to $42.93 for the same quarter last year; and (iii) higher
average wholesale energy prices per MWh in Upper New York State of US$80.89 for
the second quarter of 2008 compared to US$56.97 for the same quarter last year.
Partially offsetting the above factors was the unfavourable impact of foreign
exchange associated with the translation of foreign currency-denominated
revenue, due to the strengthening of the Canadian dollar against the US dollar
compared to the same quarter last year.
Revenue was $2 million higher year to date compared to the same period last
year. Factors increasing revenue were higher production and increased average
wholesale energy prices per MWh in Upper New York State of US$76.90 year-to-date
2008 compared to US$56.92 for the same period last year. Partially offsetting
the above factors was the unfavourable impact of foreign exchange.
Earnings: Earnings were $2 million higher quarter over quarter and $1 million
higher year to date compared to the same period last year, driven by increased
production and increased average wholesale energy prices, partially offset by
the unfavourable impact of foreign exchange associated with the translation of
foreign currency-denominated earnings.
NON-REGULATED - FORTIS PROPERTIES
--------------------------------------------------------------------------
Non-Regulated - Fortis Properties
Financial Highlights (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
($ millions) 2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Real Estate Revenue 15 14 1 31 28 3
--------------------------------------------------------------------------
Hospitality Revenue 39 33 6 68 59 9
--------------------------------------------------------------------------
Total Revenue 54 47 7 99 87 12
--------------------------------------------------------------------------
Operating Expenses 35 29 6 66 57 9
--------------------------------------------------------------------------
Amortization 3 3 - 7 6 1
--------------------------------------------------------------------------
Finance Charges 6 6 - 12 12 -
--------------------------------------------------------------------------
Corporate Taxes 3 3 - 4 4 -
--------------------------------------------------------------------------
Earnings 7 6 1 10 8 2
--------------------------------------------------------------------------
Revenue: Fortis Properties' Real Estate revenue was $1 million higher quarter
over quarter and $3 million higher year to date compared to the same period last
year. Revenue grew throughout the real estate portfolio and was also
significantly impacted by the real estate operations acquired on August 1, 2007
as part of the Delta Regina acquisition. The occupancy rate of the Real Estate
Division was 96.7 per cent as at June 30, 2008, up from 96.0 per cent as at June
30, 2007.
Hospitality Revenue was $6 million higher quarter over quarter and $9 million
higher year to date compared to the same period last year, reflecting revenue
contribution from the Delta Regina and improved performance at the Company's
hospitality operations in Atlantic Canada.
On August 1, 2007, Fortis Properties purchased the Delta Regina in Saskatchewan
for approximately $50 million, including acquisition costs. Delta Regina is
comprised of 274 hotel rooms, the Saskatchewan Trade and Convention Centre,
52,000 square feet of Class A commercial office space and a parking garage.
Revenue per available room for the second quarter was $87.54 compared to $82.11
for the same quarter last year, and year to date was $77.68 compared to $73.84
for the same period last year. The increases were mainly due to higher average
room rates.
Earnings: Fortis Properties' earnings were $1 million higher quarter over
quarter and $2 million higher year to date compared to the same period last
year. The increases reflected contributions from the Delta Regina and improved
performance at the Company's hospitality operations in Atlantic Canada.
CORPORATE AND OTHER
--------------------------------------------------------------------------
Corporate and Other (1)
Financial Highlights (Unaudited)
Quarter Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
($ millions) 2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Revenue 5 4 1 12 8 4
--------------------------------------------------------------------------
Operating Expenses 3 1 2 6 3 3
--------------------------------------------------------------------------
Amortization 1 1 - 4 2 2
--------------------------------------------------------------------------
Finance Charges (2) 20 15 5 41 26 15
--------------------------------------------------------------------------
Corporate Tax
Recovery (4) (3) (1) (9) (4) (5)
--------------------------------------------------------------------------
Preference Share
Dividends 3 2 1 4 3 1
--------------------------------------------------------------------------
Net Corporate and
Other Expenses (18) (12) (6) (34) (22) (12)
--------------------------------------------------------------------------
(1) Includes non-regulated Terasen corporate-related activities and
financial results of CWLP and TES from May 17, 2007, the date of
acquisition
(2) Includes dividends on preference shares classified as long-term
liabilities
--------------------------------------------------------------------------
The Corporate and Other segment captures expense and revenue items not
specifically related to any reportable segment. Included in this segment are
finance charges including interest on debt incurred directly by Fortis and
Terasen Inc. and dividends on preference shares classified as long-term
liabilities; dividends on preference shares classified as equity; other
corporate expenses, including Fortis and Terasen corporate operating costs, net
of recoveries from subsidiaries; interest and miscellaneous revenues; and
corporate income taxes. Also included in the Corporate and Other segment are
the financial results of CWLP. CWLP is a non-regulated shared-service business
in which Terasen holds a 30 per cent interest. CWLP operates in partnership
with Enbridge Inc. and provides customer service, meter reading, billing,
credit, support and collection services to the Terasen Gas companies and several
smaller third parties. CWLP's financial results are recorded using the
proportionate consolidation method of accounting. While currently not
significant, financial results of TES are also reported in the Corporate and
Other segment. TES is a non-regulated wholly owned subsidiary of Terasen. TES
expects to increase its activities in the development, building, owning and
operating of innovative geoexchange energy systems, community piping and energy
transfer systems to harness renewable energy sources. TES is entering into
agreements with developers to provide alternative thermal energy systems for
both residential and commercial development projects in British Columbia.
Revenue: Revenue was $1 million higher quarter over quarter and $4 million
higher year to date compared to the same period last year. The increases were
mainly due to a full quarter and half year of revenue contribution from CWLP
compared to revenue contribution during the same periods last year being from
May 17, 2007, the date of acquisition.
Net Corporate and Other Expenses: Net corporate and other expenses were $6
million higher quarter over quarter and $12 million higher year to date compared
to the same period last year. The increases reflected a full quarter and half
year of Terasen acquisition-related finance charges, Terasen corporate and CWLP
amortization costs and operating expenses, less revenue contribution from CWLP.
This compares to the inclusion, last year, of the above items in the Corporate
and other segmented results from May 17, 2007, the date of acquisition.
During the second quarter, Fortis issued 9.2 million 5.25% Five-Year Rate Reset
First Preference Shares, Series G ("First Preference Shares, Series G") for
gross proceeds of $230 million. A significant portion of the proceeds were used
to repay amounts outstanding under the Corporation's committed credit facility.
The increase in preference share dividends quarter over quarter and year to date
compared to the same period last year reflected dividends on the First
Preference Shares, Series G.
REGULATORY HIGHLIGHTS
A summary of the nature of regulation and material regulatory decisions and
applications for the Corporation's regulated utilities is as follows:
--------------------------------------------------------------------------
Nature of Regulation
--------------------------------------------------------------------------
Allowed Allowed Returns (%) Supportive Features
Common ----------------------------------------
Regulated Regulatory Equity Future or Historical
Utility Authority (%) 2006 2007 2008 Test Year Used to
Set Rates
--------------------------------------------------------------------------
ROE Cost of Service
------------------- ("COS")/ROE
PBR mechanisms
through 2009:
TGI BCUC 35 8.80 8.37 8.62 TGI: 50/50 sharing
of earnings above or
below the allowed
ROE.
TGVI BCUC 40 9.50 9.07 9.32 TGVI: 100 per cent
retention of
earnings from lower-
than-forecasted
operating and
maintenance costs
but no relief from
increased operating
and maintenance
costs
ROE automatic
adjustment formula
tied to long-term
Canada bond yields
-------------------
Future Test Year
--------------------------------------------------------------------------
FortisBC BCUC 40 9.20 8.77 9.02 COS/ROE
PBR mechanism
through 2008, with
option to continue
in 2009: 50/50
sharing of earnings
above or below the
allowed ROE up to an
achieved ROE that is
200 basis points
above or below the
allowed ROE - excess
to deferral account
ROE automatic
adjustment formula
tied to long-term
Canada bond yields
-------------------
Future Test Year
--------------------------------------------------------------------------
FortisAlberta Alberta 37 8.93 8.51 8.75 COS/ROE
Utilities
Commission
("AUC")
ROE automatic
adjustment formula
tied to long-term
Canada bond yields
--------------------------------------------------------------------------
Future Test Year
--------------------------------------------------------------------------
Newfoundland Newfoundland 45 9.24 8.60 8.95 COS/ROE
Power and Labrador +/- +/- +/-
Board of 50 bps 50 bps 50 bps
Commissioners
of Public
Utilities
("PUB")
ROE automatic
adjustment formula
tied to long-term
Canada bond yields
-------------------
Future Test Year
--------------------------------------------------------------------------
Maritime Island 40 10.25 10.25 10.00 COS/ROE
Electric Regulatory and
Appeals
Commission
("IRAC")
-------------------
Future Test Year
--------------------------------------------------------------------------
FortisOntario Ontario Energy
Board ("OEB")
(Canadian
Niagara Power)
Franchise 46.7 9.00 9.00 9.00 Canadian Niagara
Agreement Power - COS/ROE
(Cornwall
Electric)
Cornwall Electric -
Price cap with
commodity cost flow
through
-------------------
Historical
Test Year
--------------------------------------------------------------------------
ROA Four-year COS/ROA
------------------- agreements
Belize PUC N/A 10.00- 10.00- 10.00
Electricity 15.00 15.00 -------------------
Future Test Year
--------------------------------------------------------------------------
Caribbean Electricity N/A 15.00 15.00 9.00- COS/ROA
Utilities Regulatory 11.00
Authority
("ERA")
Rate-cap adjustment
mechanism based on
published consumer
price indices
-------------------
Historical Test Year
--------------------------------------------------------------------------
Fortis Turks
and Caicos Utilities make N/A 17.50 17.50 17.50 COS/ROA
annual filings
with the Energy
Commission -------------------
Future Test Year
--------------------------------------------------------------------------
--------------------------------------------------------------------------
---------------------------------------------------------------------------
Material Regulatory Decisions and Applications
---------------------------------------------------------------------------
Regulated Utility Summary Description
---------------------------------------------------------------------------
TGI - In December 2007, the BCUC approved various rates
TGVI at TGI, including those for mid-stream and
delivery for residential customers in several
service areas, effective January 1, 2008.
Increased mid-stream costs are flowed through to
customers without markup. The approved rates
also reflect the impact of an increase in the
allowed ROE for 2008 to 8.62 per cent.
- Effective April 1, 2008 and July 1, 2008, the
BCUC approved increases in the commodity rates
charged to customers for natural gas and propane
The commodity cost of natural gas and propane are
flowed through to customers without markup. Every
three months TGI and TGVI review natural gas and
propane commodity prices with the BCUC in order
to ensure the flow through rates charged to
customers are sufficient to cover the cost of
purchasing gas and propane.
- On April 1, 2008, final regulatory approval for
the construction of the 1.5 billion-cubic foot
liquefied natural gas ("LNG") facility on
Vancouver Island was received for a total
estimated cost of approximately $200 million.
---------------------------------------------------------------------------
FortisBC - In December 2007, regulatory approval was
received of the NSA associated with 2008 revenue
requirements resulting in a customer rate
increase of 2.9 per cent, effective January 1,
2008. The rate increase is primarily the result
of the Company's capital investment program.
Rates for 2008 reflect an allowed ROE of 9.02 per
cent.
- In April 2008, the BCUC approved an interim
increase of 0.8 per cent to FortisBC's customer
rates, effective May 1, 2008, as a result of BC
Hydro's recent interim rate increase, which has
increased FortisBC's cost to purchase power from
BC Hydro by 5.06 per cent.
- In June 2008, FortisBC filed its 2009 and 2010
Capital Plan for gross capital expenditures of
approximately $193 million for 2009 and $196
million for 2010. A decision on the application
is expected in the fourth quarter of 2008.
- FortisBC expects to file a 2009 Revenue
Requirements Application with the BCUC during the
fourth quarter of 2008.
---------------------------------------------------------------------------
FortisAlberta - Effective January 1, 2008, FortisAlberta is
regulated by the AUC due to the separation of the
Alberta Energy and Utilities Board into two
separate regulatory bodies.
- In February 2008, regulatory approval was
received of the NSA associated with 2008/2009
revenue requirements resulting in distribution
rate increases of 6.8 per cent, effective January
1, 2008, and 7.3 per cent, effective January 1,
2009. The approved NSA includes forecast gross
capital expenditures of approximately $264
million for 2008 and $296 million for 2009,
primarily to meet customer growth and improve
system reliability. The 2008 revenue
requirements included in the 2008/2009 NSA were
determined using the 2007 ROE of 8.51 per cent.
The impact of the increase in the ROE to 8.75 per
cent for 2008 is subject to deferral-account
treatment and, as such, is being recognized as
earned in 2008 and is expected to be collected in
future customer rates.
- In June 2008, the AUC issued a decision, ruling
that there is sufficient evidence that a review
of the ROE level, the adjustment mechanism and
utility capital structures in a generic
proceeding would be appropriate. In July 2008,
the AUC issued its notice of application,
preliminary scoping document and minimum filing
requirements for the 2009 Generic Cost of Capital
Proceeding. The Proceeding applies to all gas,
electric and pipeline utilities in Alberta that
are regulated by the AUC. A hearing is scheduled
for the first quarter of 2009.
---------------------------------------------------------------------------
Newfoundland - In December 2007, the PUB approved the Company's
Power NSA associated with the 2008 general rate
application, resulting in an average 2.8 per cent
increase in customer rates, effective January 1,
2008. The rate increase is largely driven by
higher amortization costs. The rate increase
also reflects the impact of an increase in the
allowed ROE to 8.95 per cent for 2008.
- The PUB-approved NSA will also result in, among
other things: (i) the amortization of $7.2
million in 2008 and $4.6 million in each of 2009
and 2010 of the remaining $16.4 million balance
of the original December 2005 unbilled revenue
liability; (ii) amortization of approximately
$3.9 million in each of 2008, 2009 and 2010 of
previously deferred amortization expense; (iii)
amortization over a period of three to five years
of certain deferred regulatory balances; and (iv)
for 2008 through 2010, the deferral of variations
in purchase power expense caused by differences
in the actual unit cost of energy and the unit
cost reflected in customer rates to be recovered
from, or refunded to, customers through operation
of the Company's rate stabilization account.
- Effective July 1, 2008, the PUB approved an
average 5.9 per cent increase in customer
electricity rates, reflecting the flow through to
customers, by operation of the rate stabilization
account, of variances in the cost of fuel used to
generate electricity that Newfoundland and
Labrador Hydro sells to Newfoundland Power. The
increase in customer rates will have no impact on
Newfoundland Power's earnings.
- In July 2008, the Company filed its 2009 Capital
Budget Application with the PUC for approximately
$62 million, with more than half of the proposed
capital expenditures relating to replacing aged
and deteriorated components of the electricity
system.
---------------------------------------------------------------------------
Maritime - In January 2008, IRAC approved, as filed, an
Electric increase in basic electricity rates of 1.8 per
cent, effective April 1, 2008, and approved a
maximum allowed ROE of 10.0 per cent for 2008.
- In April 2008, IRAC ordered the energy cost
adjustment mechanism ("ECAM") amortization period
of 12 months to be set at eight months, effective
May 1, 2008. The result is an increase in the
flow through in customer rates of the recovery of
ECAM over the shorter amortization period.
- In July 2008, Maritime Electric filed its 2009
Capital Budget for approximately $20 million,
before customer contributions. A decision on the
Budget is expected late in 2008.
---------------------------------------------------------------------------
FortisOntario - In March 2008, the OEB issued its decision
relating to the 2008 Incentive Regulation
Mechanism ("IRM") application filed by Canadian
Niagara Power. The result is an average 1.1 per
cent increase in electricity distribution rates
for operations in Fort Erie, Port Colborne and
Gananoque, effective May 1, 2008. The increase
is comprised of a 2.1 per cent increase for
inflation, partially offset by a 1 per cent
decrease for a productivity adjustment. Under
the 2008 IRM, Canadian Niagara Power's capital
structure will be deemed at 53.3 per cent debt
and 46.7 per cent equity, as part of the OEB's
plan to move to a 60 per cent debt and 40 per
cent equity capital structure over a three-year
period.
- Effective July 1, 2008, retail rates at Cornwall
Electric decreased by approximately 6.2 per cent,
attributable to a new 11.5 year wholesale
electricity supply contract negotiated with
Hydro-Quebec Energy Marketing by Cornwall
Electric on behalf of its customers. The new
long-term agreement replaces an existing short-
term contract and ensures reliability of supply
and rate stability.
- Canadian Niagara Power expects to file a full COS
rate application before the end of the third
quarter of 2008, for rates effective May 1, 2009,
which will result in the rebasing of distribution
rates based on a future test year.
---------------------------------------------------------------------------
Belize - In March 2008, the newly elected Government of
Electricity Belize repealed December 2007 amendments to the
Electricity (Tariffs, Charges and Quality of
Services Standards) Bylaws. The amendments had
simplified Belize Electricity's rate-setting
methodology, allowed for improved rate
stabilization and settled outstanding matters
related to the PUC's Final Decision on
electricity rates for the period July 1, 2007
through June 30, 2008.
- In March 2008, Belize Electricity filed an
application requesting an increase in the cost of
power component of the average electricity rate
by 15 per cent, or BZ6.5 cents per kWh, as a
result of the rapid increase in the cost of power
due to increasing world oil prices. The
application was disallowed by the PUC who cited
that, in the interim, a decrease in the Company's
operating expenses and capital expenditures
levels would help offset the impact on cash flow
of the increasing cost of power. Additionally,
the PUC indicated it would defer its detailed
analysis of the high deferrals of cost of power
into Belize Electricity's cost of power rate
stabilization account ("CPRSA") until the Annual
Tariff Review Proceeding for the annual tariff
period for July 1, 2008 to June 30, 2009.
- In April 2008, Belize Electricity filed its
Annual Tariff Review Application for the annual
tariff period from July 1, 2008 to June 30, 2009
("2008/2009 Rate Application") requesting a 13.4
per cent increase in the average electricity
rate, as a result of an increase in the cost of
power component of the rate and an increase in
the recovery of the CPRSA.
- In May 2008, the PUC issued its Initial Decision
on Belize Electricity's 2008/2009 Rate
Application. The Initial Decision denied any
average rate increase and approved, among other
things, a retroactive adjustment to Belize
Electricity's CPRSA. Belize Electricity objected
to the Initial Decision, which resulted in a
review of the Initial Decision by a PUC-appointed
Independent Expert. The report of the
Independent Expert echoed many of Belize
Electricity's concerns pertaining to the Initial
Decision.
- In June 2008, the PUC issued its Final Decision
on Belize Electricity's 2008/2009 Rate
Application which rejected most of the
recommendations of the Independent Expert and
failed to increase the average electricity rate.
The PUC also ordered a BZ$36 million retroactive
adjustment associated with Belize Electricity's
prior years' financial results. The adjustment,
in substance, represented the disallowance of
previously incurred fuel and purchased power
costs. The PUC also reduced Belize Electricity's
target allowed ROA to 10 per cent from 12 per
cent. The Final Decision would have the impact
of reducing Fortis' share of Belize Electricity's
earnings by approximately $5 million over the
next 12 months. The Final Decision also proposes
the future use of an automatic mechanism to
adjust on a monthly basis the cost of power
component of rates to reflect actual costs of
power. The Final Decision does not impact the
Corporation's non-regulated generation operations
in Belize.
- As a direct result of the Final Decision, Belize
Electricity has recorded an $18 million (BZ$36
million) charge ($13 million of which is Fortis'
share) to energy supply costs during the second
quarter of 2008.
- Belize Electricity filed an application for
judicial review and appeal of the Final Decision
with the Supreme Court of Belize on July 25,
2008.
---------------------------------------------------------------------------
Caribbean Utilities - In December 2007, an Agreement in Principle
("AIP") was reached with the Government of the
Cayman Islands on the terms of a new exclusive
T&D licence and a new non-exclusive generation
licence.
- In April 2008, the new licences were granted.
The terms of the new licences include competition
for future generation capacity and general
promotion of renewable resources of energy. The
T&D licence is for an initial period of 20 years,
expiring April 2028, with a provision for
automatic renewal. The generation licence is for
a period of 21.5 years, expiring September 2029.
The terms of the new licences remained
substantially the same as the terms outlined in
the AIP.
- Effective January 1, 2008, as a result of the AIP
and subsequent granting of the new licences,
basic customer rates were reduced by 3.25 per
cent, the CRS was removed, a fuel-duty rebate
funded by the Government of the Cayman Islands
was implemented for residential customers
consuming less than 1,500 kWh monthly, and basic
rates were restructured to extract all fuel costs
and licence fee amounts which are now to be fully
flowed through to customers. The 3.25 per cent
reduction in basic rates will reduce annual
revenue by approximately US$2.1 million.
Additionally, Caribbean Utilities has forgone
US$2.6 million of revenue in 2008 as a result of
the early elimination of the CRS. A new fuel and
oil rate factor was also established to provide
for full flow through of fuel and oil costs to
customers.
- Following the initial basic rate reduction,
customer rates will be frozen until May 31, 2009
and will be subject to annual review and
adjustment each June thereafter. Under the new
T&D licence, a mechanism will be used to adjust
basic rates in accordance with a formula that is
based on published consumer price indices,
thereby taking inflation into account. The rate-
adjustment mechanism is designed to maintain
Caribbean Utilities' ROA in a targeted range of 9
per cent to 11 per cent, down from an allowed ROA
of 15 per cent that was permitted under the
previous licence. The recently amended
Electricity Regularity Authority Law (2005
Revision) provides for the conduct of a
competitive bid process to be managed by the ERA
for new generating capacity and the replacement
of retired generating capacity. The first
competitive process under the new generation
licence began in May 2008 with a filing of a
Certificate of Need by Caribbean Utilities for
the installation of 16 MW of additional
generating capacity in each of 2011 and 2012.
- In July 2008, Caribbean Utilities filed with the
regulator a Five-Year Capital Investment Plan
totalling US$255 million, including US$80 million
related to new generation that is expected to be
solicited. A decision on the Plan is expected
during the second half of 2008.
- In July 2008, Caribbean Utilities began a formal
request for expressions of interest from
qualified wind-generation developers for a wind-
generation project for up to 10 MW. The ERA has
endorsed this initiative and any power purchase
agreements or generating licence arising from
this initiative will be subject to ERA approval.
---------------------------------------------------------------------------
Fortis Turks and Caicos - In March 2008, Fortis Turks and Caicos submitted
its 2007 annual regulatory filing outlining the
Company's performance in 2007 and its capital
Expansion plans for 2008. Fortis Turks and
Caicos' achieved ROA in 2007 was less than that
permitted under its licences; however, the
Company did not seek any basic rate increases in
2008.
- In May 2008, Fortis Turks and Caicos received
approval from the Government of Turks and Caicos
Islands to supply wholesale electricity under an
exclusive licence to Dellis Cay on the Turks and
Caicos Islands.
---------------------------------------------------------------------------
CONSOLIDATED FINANCIAL POSITION
The following table outlines the significant changes in the consolidated balance
sheets between June 30, 2008 and December 31, 2007.
---------------------------------------------------------------------------
Fortis Inc.
Significant Changes in the Consolidated Balance Sheets (Unaudited)
between June 30, 2008 and December 31, 2007
---------------------------------------------------------------------------
Increase/
(Decrease)
Balance Sheet Account ($ millions) Explanation
---------------------------------------------------------------------------
Accounts receivable 101 The increase was primarily due to $208
million associated with recording an
increase in the fair market value of
the natural gas derivative contracts,
which were in the money at June 30,
2008 and recorded in accounts
receivable, versus out of the money at
December 31, 2007 and recorded in
accounts payable. The increase was
partially offset by the impact of a
seasonal reduction in sales driven by
the Terasen Gas companies, FortisBC and
Newfoundland Power.
---------------------------------------------------------------------------
Regulatory assets - (65) The decrease was driven by a $79
current and long-term million decrease in regulatory
deferrals associated with the change in
the fair market value of the natural
gas derivative contracts, and the
adjustment to Belize Electricity's
CPRSA as a result of a regulatory rate
decision. The decrease was partially
offset by the deferral of an increase
in cost of fuel and power at Maritime
Electric and Caribbean Utilities and
increased AESO charges deferral amounts
at FortisAlberta.
---------------------------------------------------------------------------
Inventories of gas, (15) The decrease was driven by a normal
materials and supplies seasonal reduction of gas in storage.
---------------------------------------------------------------------------
Deferred charges and 19 The increase was mainly due to
other assets contributions made by FortisAlberta to
the AESO for transmission capital
projects, partially offset by
amortization for the six months ended
June 30, 2008.
---------------------------------------------------------------------------
Utility capital assets 214 The increase primarily related to $381
million invested in electricity and gas
systems, partially offset by
amortization for the six months ended
June 30, 2008, and the impact of
foreign exchange on the translation of
US dollar-denominated utility capital
assets.
---------------------------------------------------------------------------
Short-term borrowings (196) The decrease was primarily due to
seasonality of operations at the
Terasen Gas companies, including the
impact of decreased purchases of gas
inventories, in addition to the
repayment of short-term borrowings by
TGI and Maritime Electric with proceeds
from the issuance of long-term debt.
---------------------------------------------------------------------------
Accounts payable and (108) The decrease was driven by $79 million
accrued charges associated with recording the change in
the fair market value of the natural
gas derivative contracts, in addition
to the timing of FortisAlberta's
payments to the AESO for transmission
costs and decreased amounts owing for
purchased power at Newfoundland Power
due to seasonality of operations.
---------------------------------------------------------------------------
Income taxes payable 29 The increase was mainly due to the
timing of income tax payments and the
accrual of current income tax expense
at the Terasen Gas companies.
---------------------------------------------------------------------------
Regulatory liabilities 236 The increase was driven by a $208
- current and long-term million increase in regulatory
deferrals associated with the change in
the fair market value of the natural
gas derivative contracts.
---------------------------------------------------------------------------
Long-term debt and (17) The decrease was primarily due to a net
capital lease $477 million decrease in committed
obligations (including credit-facility borrowings, driven by
current portion) net repayments by the Terasen Gas
companies and the Corporation,
partially offset by the impact of the
issuance of long-term debt.
The issuance of long-term debt,
primarily to repay committed credit-
facility borrowings, short-term
borrowings and $188 million of maturing
long-term debt, was comprised of a $100
million senior unsecured debenture
offering by FortisAlberta, a $60
million secured first mortgage bond
issue by Maritime Electric, a $250
million unsecured debenture offering by
TGVI and a $250 million unsecured
debenture offering by TGI.
---------------------------------------------------------------------------
Shareholders' equity 292 The increase was driven by a $230
million preference share issue, $225
million net of after-tax expenses,
combined with net earnings reported for
the six months ended June 30, 2008,
less common share dividends. The
remainder of the increase related to
the issuance of Common Shares under the
Corporation's share purchase, dividend
reinvestment and stock option plans.
---------------------------------------------------------------------------
LIQUIDITY AND CAPITAL RESOURCES
The following table outlines the summary of cash flows.
--------------------------------------------------------------------------
Fortis Inc.
Summary of Cash Flows (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
($ millions) 2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Cash, beginning
of period 67 43 24 58 41 17
--------------------------------------------------------------------------
Cash provided by
(used in)
--------------------------------------------------------------------------
Operating
activities 244 68 176 432 162 270
--------------------------------------------------------------------------
Investing
activities (215) (1,429) 1,214 (358) (1,547) 1,189
--------------------------------------------------------------------------
Financing
activities (37) 1,383 (1,420) (73) 1,409 (1,482)
--------------------------------------------------------------------------
Foreign currency
impact on cash
balances - (2) 2 - (2) 2
--------------------------------------------------------------------------
Cash, end of period 59 63 (4) 59 63 (4)
--------------------------------------------------------------------------
Operating Activities: Cash flow from operating activities, after working
capital adjustments, was $176 million higher quarter over quarter. The Terasen
Gas companies contributed $142 million of the increase, due to seasonality of
operations and the fact that the Terasen Gas companies contributed to the
financial results of the Corporation last year only from May 17, 2007, the date
of acquisition. The remaining increase was driven by favourable working capital
timing differences at Newfoundland Power and FortisAlberta.
Cash flow from operating activities, after working capital adjustments, was $270
million higher year to date compared to the same period last year. An increase
in cash flow from operating activities, after working capital adjustments, of
$296 million by the Terasen Gas companies, combined with the impact of
favourable working capital timing differences and recovery of regulatory
deferral balances at Newfoundland Power, was partially offset by the impact of
the timing of the payment of AESO transmission cost accruals at FortisAlberta.
Investing Activities: Cash used in investing activities was $1.21 billion lower
quarter over quarter and $1.19 billion lower year to date compared to the same
period last year. Investing activities last year, however, included the impact
of the May 2007 acquisition of Terasen for $3.7 billion, including assumed debt
of $2.4 billion, net of cash acquired. The acquisition resulted in a cash
payment, including acquisition costs, of approximately $1.25 billion. Excluding
the impact of the investment in Terasen last year, cash used in investing
activities was $37 million higher quarter over quarter and $64 million higher
year to date compared to the same period last year. The increases were driven
by higher utility capital expenditures and changes in deferred charges, other
assets and deferred credits. Year to date, the increase was partially offset by
an increase in proceeds from the sale of capital assets, driven by $14 million
of proceeds received in January 2008 associated with the December 2007 sale of
surplus land by TGI.
Gross utility capital expenditures were $219 million for the second quarter of
2008, $26 million higher than for the same quarter last year. Gross utility
capital expenditures were $381 million year to date, $54 million higher than for
the same period last year. The increases were driven by capital expenditures
incurred at the Terasen Gas companies, partially offset by lower capital
spending at FortisBC.
The net increase in the use of cash associated with changes in deferred charges,
other assets and deferred credits of $10 million quarter over quarter and $14
million year to date compared to the same period last year was driven by higher
contributions by FortisAlberta to AESO transmission capital projects.
Financing Activities: Cash used in financing activities was $37 million during
the second quarter compared to cash provided by financing activities of $1.38
billion during the same quarter last year. Financing activities last year,
however, included the impact of the issuance of Common Shares for gross proceeds
of $1.15 billion, upon conversion of Subscription Receipts that were initially
issued in March 2007, to finance a significant portion of the cash purchase
price of Terasen. Excluding the impact of financing the acquisition of Terasen
last year, cash used in financing activities was $293 million higher quarter
over quarter and $380 million higher year to date compared to the same period
last year.
Net repayments of short-term borrowings were $163 million for the second quarter
of 2008 and $196 million year-to-date 2008. The net repayments were driven by
the Terasen Gas companies and Maritime Electric. Net repayments of short-term
borrowings were $26 million for the second quarter of 2007 and $70 million
year-to-date 2007. The net repayments were mainly due to the Terasen Gas
companies, partially offset by net borrowings by FortisBC.
Proceeds from long-term debt, net of issue costs, net (repayments) borrowings
under committed credit facilities, and repayments of long-term debt and capital
lease obligations for the quarter and year to date compared to the same periods
last year are summarized in the following tables.
--------------------------------------------------------------------------
Proceeds from Long-Term Debt, Net of Issue Costs (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
($ millions) 2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Terasen Gas
companies 247(1) - 247 496(1) - 496
(2)
--------------------------------------------------------------------------
FortisAlberta 99(3) - 99 99(3) 110(4) (11)
--------------------------------------------------------------------------
Maritime Electric 60(5) - 60 60(5) - 60
--------------------------------------------------------------------------
Caribbean Utilities - 32(6) (32) - 32(6) (32)
--------------------------------------------------------------------------
Other 3 1 2 4 1 3
--------------------------------------------------------------------------
Total 409 33 376 659 143 516
--------------------------------------------------------------------------
(1) Issued May 2008, $250 million 5.80% Medium-Term Note Debentures by TGI,
due May 2038. The net proceeds were primarily used to repay maturing
$188 million 6.20% debentures and short-term borrowings.
(2) Issued February 2008, $250 million 6.05% Medium-Term Note Debentures by
TGVI, due February 2038. The net proceeds were used to repay committed
credit-facility borrowings.
(3) Issued April 2008, $100 million 5.85% Senior Unsecured Debentures, due
April 2038. The net proceeds were used to repay committed credit-
facility borrowings.
(4) Issued January 2007, $110 million 4.99% Senior Unsecured Debentures,
due January 2047. The net proceeds were used to repay committed
credit-facility borrowings.
(5) Issued April 2008, $60 million 6.05% Secured First Mortgage Bonds, due
April 2038. The proceeds were used to repay short-term borrowings.
(6) Issued June 2007, US$30 million 5.65% Senior Unsecured Notes, due June
2022. The proceeds were used to repay debt and to finance capital
expenditures.
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Net (Repayments) Borrowings Under Committed Credit Facilities (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
($ millions) 2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Terasen Gas
companies 4 - 4 (261) - (261)
--------------------------------------------------------------------------
FortisAlberta (74) 24 (98) (2) (72) 70
--------------------------------------------------------------------------
FortisBC 8 19 (11) 8 10 (2)
--------------------------------------------------------------------------
Newfoundland Power (34) 14 (48) (14) 31 (45)
--------------------------------------------------------------------------
Corporate (170) 243 (413) (208) 213 (421)
--------------------------------------------------------------------------
Total (266) 300 (566) (477) 182 (659)
--------------------------------------------------------------------------
Borrowings by the utilities under committed credit facilities are primarily in
support of their respective capital expenditure programs and/or for working
capital requirements. Repayments are primarily financed through the issuance of
long-term debt and/or cash from operations. From time to time, proceeds from
preference share, common share and long-term debt issuances are used to repay
borrowings under the Corporation's committed credit facility. During the second
quarter of 2008, a net repayment of $170 million under the Corporation's
committed credit facility was financed with partial proceeds from the issuance
of $230 million preference shares ($223 million net of costs). The remaining
proceeds from the preference share offering were lent to Newfoundland Power to
repay certain committed credit-facility borrowings, and were used for other
general corporate purposes. During the second quarter last year, borrowings
under the Corporation's committed credit facility primarily related to
financing, on an interim basis, the remaining $125 million net cash purchase
price of Terasen on May 17, 2007, in addition to certain acquisition costs and
Common Share issuance costs; to repay certain short-term indebtedness assumed
upon the acquisition of Terasen; and for general corporate purposes. During the
first quarter last year, the Corporation repaid approximately $84 million of
committed credit-facility borrowings financed with partial proceeds from a 5.17
million Common Share issuance in January 2007.
--------------------------------------------------------------------------
Repayments of Long-Term Debt and Capital Lease Obligations (Unaudited)
Periods Ended June 30
--------------------------------------------------------------------------
Quarter Year-to-date
--------------------------------------------------------------------------
($ millions) 2008 2007 Variance 2008 2007 Variance
--------------------------------------------------------------------------
Terasen Gas
companies (194) - (194) (194) - (194)
--------------------------------------------------------------------------
Fortis Properties (3) (3) - (6) (14) 8
--------------------------------------------------------------------------
Other (3) (13) 10 (5) (19) 14
--------------------------------------------------------------------------
Total (200) (16) (184) (205) (33) (172)
--------------------------------------------------------------------------
In May 2008, partial proceeds from TGI's $250 million debenture offering were
used to repay maturing $188 million 6.20% debentures.
Net proceeds associated with the issuance of Common Shares under the
Corporation's share purchase and stock options plans during the second quarter
were $5 million compared to $4 million for the same quarter last year and were
$11 million year to date compared to $9 million for the same period last year.
On May 17, 2007, the Corporation publicly issued 44.3 million Common Shares for
gross proceeds of approximately $1.15 billion ($1.1 billion net of costs) upon
conversion of Subscription Receipts that were initially issued in March 2007 to
finance a significant portion of the net cash purchase price of Terasen. In
January 2007, 5.17 million Common Shares were publicly issued for gross proceeds
of approximately $150 million ($143 million net of costs). Partial net proceeds
from the Common Share issue in January 2007 were used to repay indebtedness
incurred under the Corporation's committed credit facility. The remainder of
the net proceeds was utilized to fund equity requirements of the Corporation's
regulated electric utilities in western Canada, in support of their respective
capital expenditure programs, and for general corporate purposes.
Common Share dividends were $40 million during the second quarter of 2008, up $8
million from the same quarter last year. The increase was primarily due to a
higher dividend per Common Share compared to the same quarter last year. Common
share dividends were $79 million year to date, up $23 million from the same
period last year. The increase was due to an increase in the number of Common
Shares outstanding, primarily as a result of the issuance of Common Shares
pursuant to the Terasen acquisition in May 2007, and a higher dividend per
Common Share compared to the same period last year. The dividend per Common
Share for each of the first and second quarters of 2008 was $0.25, while the
dividend per Common Share for each of the first and second quarters of last year
was $0.21.
Preference share dividends increased $1 million quarter over quarter and
increased $1 million year to date compared to the same period last year related
to the 9.2 million First Preference shares, Series G issued during the second
quarter of 2008.
Contractual obligations: Consolidated contractual obligations of Fortis over the
next five years and for periods thereafter, as at June 30, 2008, are outlined in
the following table. The nature and amount of the contractual obligations are
consistent with those disclosed in the MD&A for the year ended December 31,
2007, except for those described below for FortisOntario, Maritime Electric,
Caribbean Utilities and Fortis Turks and Caicos.
--------------------------------------------------------------------------
Fortis Inc.
Contractual Obligations (Unaudited)
as at June 30, 2008
--------------------------------------------------------------------------
lesser
or
egual greater greater
than than 1- than
($ millions) Total 1 year 3 years 4-5 years 5 years
--------------------------------------------------------------------------
Long-term debt 5,043 335 314 123 4,271
--------------------------------------------------------------------------
Brilliant Terminal Station 64 3 5 5 51
--------------------------------------------------------------------------
Gas purchase contract
obligations (based on index
prices as at June 30, 2008) 639 626 13 - -
--------------------------------------------------------------------------
Power purchase obligations
FortisBC 2,835 38 75 74 2,648
FortisOntario (1) 583 45 93 86 359
Maritime Electric (2) 108 71 18 2 17
Belize Electricity 11 1 2 2 6
--------------------------------------------------------------------------
Capital cost 395 14 37 37 307
--------------------------------------------------------------------------
Joint-use asset and shared
service agreements 66 2 8 6 50
--------------------------------------------------------------------------
Office lease - FortisBC 20 - 4 2 14
--------------------------------------------------------------------------
Operating lease obligations 167 18 33 29 87
--------------------------------------------------------------------------
Equipment purchase commitment
- Caribbean Utilities (3) 20 12 8 - -
--------------------------------------------------------------------------
Other 26 5 9 7 5
--------------------------------------------------------------------------
Total 9,977 1,170 619 373 7,815
--------------------------------------------------------------------------
(1) Included in FortisOntario's power purchase obligations is a new 11.5
year take-or-pay contract between Cornwall Electric and Hydro-Quebec
Energy Marketing for the supply of electricity and capacity. The
contract, which expires on December 31, 2019, replaces the previous
two-year contract that expired on June 30, 2008. This take-or-pay
contract provides energy up to 100 MW on an as-needed basis and
provides a minimum 300,000 MWh of energy per contract year beginning
July 1, 2008.
(2) Maritime Electric has two new take-or-pay contracts for the purchase of
either energy or capacity. The contracts total approximately $108
million through November 30, 2032. The take-or-pay contract with New
Brunswick Power includes, among other things, replacement energy and
capacity for the Point Lepreau Nuclear Generating Station during its
18-month refurbishment outage. The other take-or-pay contract is for
transmission capacity allowing Maritime Electric to reserve 30 MW of
capacity on the new International Power Line into the United States.
(3) Caribbean Utilities has entered into a project agreement to purchase a
16-MW diesel generating unit and related equipment from a supplier in
Germany for approximately US$24 million. The unit is expected to be
commissioned in summer 2009. Approximately US$5 million has been
incurred under the project as at June 30, 2008.
Other Contractual Obligations:
Caribbean Utilities has a primary fuel supply contract with a major
supplier and is committed to purchase 80 per cent of the Company's fuel
requirements from this supplier for the operation of Caribbean Utilities'
diesel-fired generating plant. The contract is for three years terminating
in April 2010. The remaining approximate quantities, in millions of
imperial gallons, required to be purchased annually during Caribbean
Utilities' fiscal years ended April 30 are: 2009 - 26 and 2010 - 28.
Fortis Turks and Caicos has a renewable contract with a major supplier for
all of its diesel fuel requirements associated with the generation of
electricity. The approximate fuel requirements under this contract are 12
million imperial gallons per annum.
--------------------------------------------------------------------------
Capital Structure: The Corporation's principal businesses of regulated gas and
electricity distribution require ongoing access to capital to allow them to fund
maintenance and expansion of infrastructure. Wherever possible, Fortis raises
debt at the subsidiary level to ensure regulatory transparency, tax efficiency
and financing flexibility. To help ensure access to capital, the Corporation
targets a consolidated long-term capital structure containing approximately 40
per cent equity, including preference shares, 60 per cent debt and
investment-grade credit ratings.
Each of the Corporation's regulated utilities maintains its own capital
structure in line with the deemed capital structure reflected in the utility's
customer rates. As well, the Corporation and its larger regulated utilities
have secured multi-year committed credit facilities to support short-term
financing of capital expenditures and seasonal working capital requirements.
The committed credit facility at Fortis is available for interim financing of
acquisitions and for general corporate purposes. Fortis generally finances a
significant portion of acquisitions with proceeds from common and preference
share issuances.
The consolidated capital structure of Fortis is presented in the following table.
--------------------------------------------------------------------------
Fortis Inc.
Capital Structure (Unaudited)
As at
--------------------------------------------------------------------------
June 30, 2008 December 31, 2007
--------------------------------------------------------------------------
($ millions) (%) ($ millions) (%)
--------------------------------------------------------------------------
Total debt and capital lease
obligations (net of cash) (1) 5,262 61.2 5,476 64.3
--------------------------------------------------------------------------
Preference shares (2) 667 7.8 442 5.2
--------------------------------------------------------------------------
Common shareholders' equity 2,668 31.0 2,601 30.5
--------------------------------------------------------------------------
Total 8,597 100.0 8,519 100.0
--------------------------------------------------------------------------
(1) Includes long-term debt, including current portion, and short-term
borrowings, net of cash
(2) Includes preference shares classified as both long-term liabilities and
equity
--------------------------------------------------------------------------
The improvement in the capital structure from December 2007 was primarily due to
reduced consolidated debt driven by the repayment of credit facility borrowings
by the Corporation with partial proceeds from the $230 million, $225 million net
of after-tax expenses, issuance of preference shares combined with the seasonal
reduction of credit facility borrowings at the Terasen Gas companies, partially
offset by increased debt levels at FortisAlberta in support of its significant
capital expenditure program. The capital structure was also favourably impacted
by net earnings applicable to common shares, less common share dividends, of $41
million during the first half of 2008.
The Corporation's credit ratings are as follows:
S&P A- (long-term corporate and unsecured debt credit rating)
DBRS BBB(high) (unsecured debt credit rating)
The credit ratings reflect the diversity of the operations of Fortis, the
stand-alone nature and financial separation of each of the regulated
subsidiaries of Fortis, management's commitment to maintaining low levels of
debt at the holding company level and the continued focus of Fortis on pursuing
acquisitions in stable regulated utilities.
Capital Program: The Corporation's principal businesses of regulated gas and
electricity distribution are capital intensive. Capital investment in
infrastructure is required to ensure continued and enhanced performance,
reliability and safety of the gas and electricity systems and to meet customer
growth. All costs considered to be maintenance and repairs are expensed as
incurred. Costs related to replacements, upgrades and betterments of capital
assets are capitalized as incurred.
During the first half of 2008, gross consolidated capital expenditures were $389
million. A breakdown of gross capital expenditures for the first half of 2008
by segment is provided in the following table.
---------------------------------------------------------------------------
Gross Capital Expenditures (Unaudited)
Year-to-date June 30, 2008
---------------------------------------------------------------------------
($ Tera- Fortis Fortis- NF Other Total Fortis Total
millions) sen Alberta BC(1)Power Regula-Regula-Regula- Non Proper- (4)
Gas (1)(2) (1) ted ted ted Regula- ties
Compa- Utili- Utili- Utili- ted
nies Ties Ties Ties Utilty
(1) Cana- Cana- Carib- (3)
Dian Dian bean
(1)
---------------------------------------------------------------------------
Total 96 144 50 30 17 337 34 10 8 389
---------------------------------------------------------------------------
(1) Includes removal and site restoration expenditures which are
permissible in rate base
(2) Excludes payments of $14 million made to the AESO for investment in
transmission capital projects
(3) Includes non-regulated generation, non-regulated gas utility and
Corporate capital expenditures
(4) Includes expenditures associated with assets under construction
---------------------------------------------------------------------------
Gross consolidated capital expenditures for 2008 are expected to exceed $900
million. Planned capital expenditures are based on detailed forecasts of energy
demand, weather, cost of labour and materials, as well as other factors which
could change and cause actual expenditures to differ from forecasts. The
significant changes in the expected level, nature and timing of certain capital
projects for 2008 from those disclosed in the MD&A for the year ended December
31, 2007, are described below.
In April 2008, TGVI received approval from the BCUC to proceed with the
engineering, procurement and construction ("EPC") of the LNG storage facility on
Vancouver Island for a total cost of approximately $200 million. As a result,
the Company entered into an EPC contract with a third party for the construction
of the facility. The contract includes approximately $55 million to be paid in
US dollars. As a result, TGVI has entered into a three-year US dollar
forward-purchase contract which will mitigate currency fluctuations on the US
dollar portion of the EPC contract. During the second quarter, construction
commenced on the LNG storage facility.
TGVI's construction of the 50-kilometre pipeline lateral from Squamish to
Whistler continues and, as at the end of June 2008, approximately 37 kilometres
of the pipeline had been constructed. Originally scheduled to be completed by
summer 2008, the pipeline lateral is now expected to be completed in early 2009,
slightly later than originally planned, due to changes in the way the Company
can sequence the pipeline construction as a result of the Province's Sea-to-Sky
Highway Improvement Project ("Highway Project") Plan. The pipeline is being
built in conjunction with the Highway Project Plan and the pipeline route mainly
falls within the highway right of way. Conversion of the Resort Municipality of
Whistler from propane to natural gas will occur in spring 2009 and take
approximately three months to complete. TGVI does not expect any material
changes in the cost to complete this capital project as a result of this delay.
As disclosed in the MD&A for the year ended December 31, 2007, FortisAlberta
plans to expend approximately $24 million in 2008 on the second phase of
replacement of conventional meters with new Automated Meter Infrastructure
("AMI") technology as part of an overall $111 million project to convert
approximately 435,000 customers to such technology over a four-year period that
began in 2007. The second phase of the deployment of the AMI technology is
expected to be concentrated during the second half of 2008. FortisAlberta's
gross capital expenditures for 2008 are expected to be approximately $22 million
higher than originally planned gross capital expenditures of $264 million, as
disclosed at December 31, 2007, mainly due to customer growth and increased
labour costs.
In April 2008, Caribbean Utilities entered into a project agreement to purchase
a 16-MW diesel generating unit and related equipment from a supplier in Germany
for approximately US$24 million over the period 2008 and 2009 with the unit
expected to be commissioned by September 2009.
Maritime Electric expects gross capital expenditures for 2008 to be
approximately $17 million higher than originally planned, mainly due to the
construction of an approximate 66-kilometre transmission line for merchant wind
developers. The project is being financed entirely by customer contributions.
Fortis expects gross consolidated capital expenditures to exceed $4.5 billion
over the next five years and to be driven by the Terasen Gas companies,
FortisAlberta, FortisBC and the Corporation's regulated and non-regulated
electric utility operations in the Caribbean. The increase in the expected
capital expenditures over the next five years from the original estimate of $4
billion arises from additional capital projects forecasted by the Terasen Gas
companies, FortisBC and Caribbean Utilities.
Cash Flows: At the operating subsidiary level, it is expected that operating
expenses and interest costs will generally be paid out of subsidiary operating
cash flows, with varying levels of residual cash flow available for dividend
payments to Fortis and/or for subsidiary capital expenditures. Borrowings under
credit facilities may be required from time to time to support seasonal working
capital requirements. Cash required to complete subsidiary capital expenditure
programs is also expected to be financed from a combination of borrowings under
credit facilities, equity injections from Fortis and long-term debt issuances.
The Corporation's ability to service its debt obligations and pay dividends on
its common shares and preference shares is dependent on the financial results of
the operating subsidiaries and the related cash payments from these
subsidiaries. Certain regulated subsidiaries may be subject to restrictions
which may limit their ability to distribute cash to Fortis. Cash required of
Fortis to support subsidiary capital expenditure programs and to finance
acquisitions is expected to be derived from a combination of borrowings under
credit facilities and the issuance of common shares, preference shares and
long-term debt. Depending on the timing of cash payments from the subsidiaries,
borrowings under the Corporation's credit facilities may be required from time
to time to support the servicing of debt and payment of dividends. Fortis and
its subsidiaries do not anticipate any difficulties accessing required capital
at reasonable market terms.
As a result of the PUC's Final Decision on Belize Electricity's 2008/2009 rate
application, Belize Electricity does not meet certain debt covenant financial
ratios resulting in approximately $16 million (BZ$30 million) of indebtedness
being in default as at June 30, 2008. In accordance with certain of these debt
covenants, Belize Electricity is also prohibited from incurring new indebtedness
or declaring dividends. The Company has informed the lenders of the situation
and has requested appropriate waivers. As at June 30, 2008, $10 million of the
above debt was reclassified from long-term to current on the balance sheet.
As at June 30, 2008, the Corporation and its subsidiaries had consolidated
authorized lines of credit of $2.2 billion, of which $1.8 billion was unused.
The following summary outlines the credit facilities of the Corporation and its
subsidiaries.
-------------------------------------------------------------------------
Fortis Inc.
Credit Facilities (Unaudited)
-------------------------------------------------------------------------
($ millions) Corporate Regulated Fortis Total as at Total as at
and Other Utilities Properties June 30, December 31,
2008 2007
-------------------------------------------------------------------------
Total credit
facilities 715 1,490 13 2,218 2,234
-------------------------------------------------------------------------
Credit facilities
utilized:
-------------------------------------------------------------------------
Short-term
Borrowings - (279) - (279) (475)
-------------------------------------------------------------------------
Long-term debt
(including
current
portion) - (54) - (54) (530)
-------------------------------------------------------------------------
Letters of credit
outstanding (1) (89) (1) (91) (159)
-------------------------------------------------------------------------
Credit facilities
available 714 1,068 12 1,794 1,070
-------------------------------------------------------------------------
At June 30, 2008 and December 31, 2007, certain borrowings under the
Corporation's and subsidiaries' credit facilities have been classified as
long-term debt. These borrowings are under long-term committed credit facilities
and management's intention is to refinance these borrowings with long-term
permanent financing during future periods.
Corporate and Other
Letters of credit of $50 million previously outstanding at Terasen Inc., related
to its previously owned petroleum transportation business and secured by a
letter of credit from the former parent company, were cancelled during the
second quarter of 2008.
Regulated Utilities
In April 2008, FortisBC renegotiated and amended its $150 million unsecured
committed revolving credit facility, extending the maturity date of the $50
million portion of the facility to May 2011 from May 2010 and extending the $100
million portion to May 2009 from May 2008. The Company has the option to
increase the credit facility to an aggregate of $200 million, subject to bank
approval.
In April 2008, Maritime Electric repaid all outstanding borrowings under its $25
million unsecured credit facility with partial proceeds from a $60 million bond
issue. The credit facility matured in May 2008 and was not renewed. As at June
30, 3008, Maritime Electric had a $45 million unsecured revolving credit
facility.
In July 2008, TGI renegotiated its $500 million unsecured committed revolving
credit facility extending the maturity date of the facility to August 2013 from
August 2012.
FINANCIAL INSTRUMENTS
The carrying values of financial instruments included in current assets, current
liabilities, deferred charges and other assets, and deferred credits in the
consolidated balance sheets of Fortis approximate their fair value, reflecting
the short-term maturity, normal trade credit terms and/or nature of these
instruments. The fair value of long-term debt is calculated by using quoted
market prices when available, or by discounting the future cash flow of each
debt instrument at the estimated yield to maturity for the same or similar debt
issues at the balance sheet date. Since the Corporation does not intend to
settle the long-term debt prior to maturity, the fair value estimate does not
represent an actual liability and, therefore, does not include exchange or
settlement costs. The fair value of the Corporation's preference shares is
determined using quoted market prices.
The carrying and fair values of the Corporation's long-term debt and preference
shares are as follows.
--------------------------------------------------------------------------
Financial Instruments (Unaudited)
As at
--------------------------------------------------------------------------
June 30, 2008 December 31, 2007
--------------------------------------------------------------------------
($ millions) Carrying Estimated Carrying Estimated
Value Fair Value Value Fair Value
--------------------------------------------------------------------------
Long-term debt 5,006 5,483 5,023 5,635
--------------------------------------------------------------------------
Preference shares, classified
as debt (1) 320 340 320 346
--------------------------------------------------------------------------
(1) Preference shares classified as equity do not meet the definition of a
financial instrument; however, the estimated fair value of the
Corporation's $347 million preference shares classified as equity was
$326 million as at June 30, 2008 (December 31, 2007: carrying value
$122 million; fair value $107 million).
--------------------------------------------------------------------------
Risk Management: The Corporation's earnings from and net investment in
self-sustaining foreign subsidiaries are exposed to changes in the US
dollar-to-Canadian dollar exchange rate. The Corporation has effectively
decreased the above exposure through the use of US dollar borrowings. As at
June 30, 2008, all of the Corporation's US$390 million of long-term debt had
been designated as a hedge of a portion of the Corporation's foreign net
investments. Foreign currency exchange rate fluctuations associated with the
translation of the Corporation's US dollar borrowings designated as hedges of
the Corporation's foreign net investments are recorded in other comprehensive
income. As at June 30, 2008, the Corporation had approximately US$72 million in
foreign net investments remaining to be hedged.
The Corporation also hedges exposures to fluctuations in interest rates, foreign
exchange rates and natural gas commodity prices through the use of derivative
financial instruments. The Corporation does not hold or issue derivative
financial instruments for trading purposes. The following table summarizes the
valuation of the Corporation's derivative financial instruments.
------------------------------------------------------------------------
Derivative Financial Instruments (Unaudited)
As at
------------------------------------------------------------------------
June 30, 2008 December 31, 2007
------------------------------------------------------------------------
(Liability) Term to Carrying Estimated Carrying Estimated
Asset maturity Number of Value Fair Value Value Fair Value
(years) Contracts ($ ($ ($ ($
millions) millions) millions) millions)
------------------------------------------------------------------------
Interest
rate swaps 1 to 2 4 (1) (1) - -
------------------------------------------------------------------------
Foreign
exchange
forward
contract 3 1 - - - -
------------------------------------------------------------------------
Natural gas
derivatives:
------------------------------------------------------------------------
Swaps and
options Up to 3 214 212 212 (79) (79)
------------------------------------------------------------------------
Gas purchase
contract
premiums less 53 1 1 5 5
than 1
------------------------------------------------------------------------
Two of the four interest rate swaps are held by Fortis Properties and are
designated as hedges of the cash flow risk related to floating-rate long-term
debt. The effective portion of changes in the value of the interest rate swaps
at Fortis Properties is recorded in other comprehensive income. The remaining
interest rate swaps and all of the natural gas derivatives are held by the
Terasen Gas companies. The interest rate swaps are designated as hedges of cash
flow risk related to floating-rate debt instruments. The natural gas
derivatives are used to fix the effective purchase price of natural gas, as the
majority of the natural gas supply contracts have floating, rather than fixed,
prices. The foreign exchange forward contract is held by TGVI and is designated
as a hedge of the cash flow risk related to approximately US$55 million required
to be paid under a contract for the construction of an LNG storage facility.
The carrying value and estimated fair value of the foreign exchange forward
contract were immaterial as at June 30, 2008.
At the Terasen Gas companies, changes in the fair value of the interest rate
swaps, foreign exchange forward contracts and natural gas derivatives are
deferred as a regulatory asset or liability, subject to regulatory approval, for
recovery from, or refund to, customers in future rates. The fair values of the
natural gas derivatives were recorded in accounts receivable as at June 30, 2008
(December 31, 2007 - accounts payable and accounts receivable).
The interest rate swaps are valued at the present value of future cash flows
based on published forward future interest rate curves. The foreign exchange
forward contract is valued using the present value of future cash flows based on
published forward future foreign exchange market rate curves. The fair values
of the natural gas derivatives reflect the estimated amounts, based on published
forward curves, that the Corporation would have to receive or pay if forced to
settle all outstanding contracts at the balance sheet date.
The fair value of the Corporation's financial instruments, including
derivatives, reflects a point-in-time estimate based on relevant market
information about the instruments. The estimates cannot be determined with
precision as they involve uncertainties and matters of judgment and, therefore,
may not be relevant in predicting the Corporation's future earnings or cash
flows.
OFF-BALANCE SHEET ARRANGEMENTS
As at June 30, 2008, the Corporation had no off-balance sheet arrangements such
as transactions, agreements or contractual arrangements with unconsolidated
entities, structured finance entities, special purpose entities or variable
interest entities, that are reasonably likely to materially affect liquidity or
the availability of, or requirements for, capital resources.
BUSINESS RISK MANAGEMENT
Changes in the Corporation's significant business risks during the six months
ended June 30, 2008 from those disclosed in the Corporation's MD&A for the year
ended December 31, 2007 are described below.
Regulation: The PUC's June 2008 Final Decision on Belize Electricity's rate
application for the period July 1, 2008 through June 30, 2009 creates
uncertainty in the regulatory regime and the rate setting process in Belize.
The PUC ordered a BZ$36 million ($18 million; $13 million of which is Fortis'
share) retroactive adjustment associated with Belize Electricity's prior years'
financial results. The adjustment, in substance, represented the disallowance
of previously incurred fuel and purchased power costs. The PUC also reduced
Belize Electricity's allowed ROA to 10 per cent from 12 per cent. The Final
Decision violates both established regulatory practice and contractual
obligations made by the Government of Belize at the time Fortis made its initial
investment in Belize Electricity. Belize Electricity filed an application for
judicial review and appeal of the Final Decision with the Supreme Court of
Belize on July 25, 2008.
Integration of Terasen: Management considers the integration of Terasen within
the Fortis Group to be substantially complete and, therefore, the risk related
to integration has been reduced.
Labour Relations: In July 2008, Belize Electricity and the Belize Energy
Worker's Union, through a process of conciliation, entered into a new collective
agreement, which provided for retroactive wage increases of 2.5 per cent,
effective for each of June 1, 2006 and June 1, 2007, in addition to wage
increases of 2 per cent and 1 per cent, effective June 1, 2008 and June 1, 2009,
respectively. Reaching a new collective agreement concluded a negotiation and
subsequent conciliation process that commenced in 2006. The next review of the
collective agreement will be in 2011.
CHANGES IN ACCOUNTING STANDARDS
Inventories: Effective January 1, 2008, the Corporation adopted the new Canadian
Institute of Chartered Accountants ("CICA") Handbook Section 3031 - Inventories.
The new standard requires inventories to be measured at the lower of cost or
net realizable value; disallows the use of a last-in first-out inventory-costing
methodology; and requires that, when circumstances which previously caused
inventories to be written down below cost or net realizable value no longer
exist, the amount of the write down is to be reversed. As at December 31, 2007,
inventories of $26 million were reclassified to property, plant and equipment
from inventory on the balance sheet as they were held for the development,
construction, maintenance and repair of other property, plant and equipment.
This new standard did not have a material impact on the Corporation's earnings,
cash flow or financial position.
Capital Disclosures: Effective January 1, 2008, the Corporation adopted the new
CICA Handbook Section 1535 - Capital Disclosures. The new standard requires
additional information to be disclosed in the Notes to the financial statements
about the Corporation's capital and the manner in which it is managed. The
additional disclosures include quantitative and qualitative information
regarding the Corporation's objectives, policies and processes for managing
capital. This new standard did not have a material impact on the Corporation's
earnings, cash flow or financial position. The additional required disclosures
are provided in Note 16 to the Corporation's unaudited interim consolidated
financial statements for the three and six months ended June 30, 2008.
Disclosure and Presentation of Financial Instruments: Effective January 1, 2008,
the Corporation adopted new accounting recommendations for disclosure and
presentation of financial instruments provided in Sections 3862 and 3863 of the
CICA Handbook. The new recommendations require disclosures of both qualitative
and quantitative information that enables users of financial statements to
evaluate the nature and extent of risks from financial instruments to which the
Corporation is exposed. The new standards did not have a material impact on the
Corporation's earnings, cash flow or financial position. The additional
required disclosures are provided in Notes 17 and 18 to the Corporation's
unaudited interim consolidated financial statements for the three and six months
ended June 30, 2008.
FUTURE ACCOUNTING PRONOUNCEMENTS
International Financial Reporting Standards ("IFRS"): In February 2008, the
Accounting Standards Board ("AcSB") confirmed that the use of IFRS will be
required in 2011 for publicly accountable enterprises in Canada. In April 2008,
the AcSB issued an IFRS Omnibus Exposure Draft proposing that publicly
accountable enterprises be required to apply IFRS, in full and without
modification, on January 1, 2011. The transition date of January 1, 2011 will
require the restatement, for comparative purposes, of amounts reported by the
Corporation for its year ended December 31, 2010, and of the opening balance
sheet as at January 1, 2010. The AcSB proposes that CICA Handbook Section -
Accounting Changes, paragraph 1506.30, which would require an entity to disclose
information relating to a new primary source of GAAP that has been issued but is
not yet effective and that the entity has not applied, not be applied with
respect to this Exposure Draft. Fortis is continuing to assess the financial
reporting impacts of the adoption of IFRS and, at this time, the impact on
future financial position and results of operations is not reasonably
determinable or estimable. Further, Fortis anticipates a significant increase
in disclosure resulting from the adoption of IFRS and is continuing to assess
the level of disclosure required and any necessary system changes to gather and
process the information.
Fortis commenced its IFRS conversion project in 2007 and has established a
formal project governance structure. Regular reporting will occur to the Audit
Committee of the Board of Directors of Fortis Inc. and of the subsidiaries,
where appropriate. An external expert advisor has been engaged to assist in the
IFRS conversion project.
The Fortis IFRS conversion project consists of three phases: scoping and
diagnostic, analysis and development, and implementation and review. Phase One
has been completed which involved project planning and staffing, and
identification of differences between current Canadian GAAP and IFRS. Currently,
the identified areas of accounting difference of highest potential impact to
Fortis are rate-regulated operations, property plant and equipment, investment
property, intangible assets, employee benefits, impairment of assets, income
taxes, business combinations, and initial adoption of IFRS under the provisions
of IFRS 1 - First-Time Adoption of IFRS.
Phase Two, currently in progress, involves completion of detailed diagnostics
and evaluation of the financial impacts of various options and alternative
methodologies provided for under IFRS; identification and design of operational
and financial business processes; and development of required solutions to
address identified issues.
It is anticipated that the adoption of IFRS will have an impact on current and
future system requirements. The degree of this impact is not reasonably
determinable at this stage of the project.
During the first half of 2008, several regulatory authorities with jurisdiction
over the Corporation's regulated utilities have begun their own IFRS projects to
determine the nature of any changes that should be made in regulatory accounting
requirements in response to IFRS. The Corporation's regulated utilities will
work with their respective regulatory authority to identify transitional issues
and suggest how those issues might be addressed.
Fortis will continue to review all proposed and continuing projects of the
International Accounting Standards Board, closely monitor any International
Financial Reporting Interpretations Committee initiatives with the potential to
impact rate-regulated accounting under IFRS, and will participate in any related
processes, as appropriate.
Rate-Regulated Operations: In March 2007, the AcSB issued an Exposure Draft on
rate-regulated operations that proposed: (i) the temporary exemption in Section
1100, Generally Accepted Accounting Principles, of the CICA Handbook providing
relief to entities subject to rate regulation from the requirement to apply the
Section to the recognition and measurement of assets and liabilities arising
from rate regulation be removed; (ii) the explicit guidance for rate-regulated
operations provided in Section 1600, Consolidated Financial Statements, Section
3061, Property, Plant and Equipment, Section 3465, Income Taxes, and Section
3475, Disposal of Long-Lived Assets and Discontinued Operations, be removed; and
(iii) Accounting Guideline 19, Disclosures by Entities Subject to Rate
Regulation ("AcG-19"), be retained as is.
In August 2007, the AcSB issued a Decision Summary on the Exposure Draft that
supported the removal of the temporary exemption in Section 1100, Generally
Accepted Accounting Principles, and the amendment to Section 3465, Income Taxes,
to recognize future income tax liabilities and assets as well as offsetting
regulatory assets and liabilities by entities subject to rate regulation. Both
changes will apply prospectively for fiscal years beginning on or after January
1, 2009. The AcSB also decided that the current guidance for rate-regulated
operations pertaining to property, plant and equipment, disposal of long-lived
assets and discontinued operations, and consolidated financial statements be
maintained, and that the existing AcG-19 will not be withdrawn from the CICA
Handbook but that the guidance will be updated as a result of the other changes.
The AcSB also decided that the final Background Information and Basis for
Conclusions associated with its rate-regulation project would not express any
views of the AcSB regarding the status of US Statement of Financial Accounting
Standards No. 71, Accounting for the Effects of Certain Types of Regulation, as
"another source of GAAP" within the Canadian GAAP hierarchy.
Effective January 1, 2009, the impact on Fortis of the amendment to Section
3465, Income Taxes, will be the recognition of future income tax assets and
liabilities and related regulatory liabilities and assets for the amount of
future income taxes expected to be refunded to, or recovered from, customers in
future gas and electricity rates. Currently, the Terasen Gas companies,
FortisAlberta, FortisBC and Newfoundland Power use the taxes payable method of
accounting for income taxes. The effect on the Corporation's interim unaudited
consolidated financial statements, if it had adopted amended Section 3465,
Income Taxes, as at June 30, 2008, would have been an increase in future income
tax assets and future income tax liabilities of $37 million and $465 million,
respectively, and a corresponding increase in regulatory liabilities and
regulatory assets of $37 million and $465 million, respectively. Included in
the amounts are the future income tax effects of the subsequent settlement of
the related regulatory assets and liabilities through customer rates, and the
separate disclosure of future income tax assets and liabilities that are
currently not recognized. Fortis is continuing to assess and monitor any
additional implications on its financial reporting related to accounting for
rate-regulated operations.
Goodwill and Intangible Assets: Effective January 1, 2009, the Corporation will
be adopting the new CICA Handbook Section 3064 - Goodwill and Intangible Assets.
This Section, which replaces Section 3062, Goodwill and Other Intangible
Assets, and Section 3450, Research and Development Costs, establishes standards
for the recognition, measurement and disclosure of goodwill and intangible
assets. The provisions related to the definition and initial recognition of
intangible assets, including internally generated intangible assets, are
equivalent to the corresponding provisions of International Accounting Standard
38, Intangible Assets. The Corporation is continuing to assess the financial
reporting impact of adopting this standard.
CRITICAL ACCOUNTING ESTIMATES
The preparation of the Corporation's interim unaudited consolidated financial
statements in accordance with Canadian GAAP requires management to make
estimates and judgments that affect the reported amounts of assets and
liabilities and the disclosure of contingent assets and liabilities at the date
of the financial statements and the reported amounts of revenue and expenses
during the reporting periods. Estimates and judgments are based on historical
experience, current conditions and various other assumptions believed to be
reasonable under the circumstances. Additionally, certain estimates and
judgments are necessary since the regulatory environments in which the
Corporation's utilities operate often require amounts to be recorded at
estimated values until these amounts are finalized pursuant to regulatory
decisions or other regulatory proceedings. Due to changes in facts and
circumstances and the inherent uncertainty involved in making estimates, actual
results may differ significantly from current estimates. Estimates and
judgments are reviewed periodically and, as adjustments become necessary, are
reported in earnings in the period they become known.
Interim financial statements may also employ a greater use of estimates than the
annual financial statements. There were no material changes in the nature of
the Corporation's critical accounting estimates during the six months ended June
30, 2008 from those disclosed in the Corporation's MD&A for the year ended
December 31, 2007.
Contingencies: Fortis is subject to various legal proceedings and claims that
arise in the ordinary course of business operations. Management believes that
the amount of liability, if any, from these actions would not have a material
effect on the Corporation's financial position or results of operations. There
were no material changes in the Corporation's contingent liabilities during the
six months ended June 30, 2008 from those disclosed in the MD&A for the year
ended December 31, 2007.
QUARTERLY RESULTS
The following table sets forth unaudited quarterly information for each of the
eight quarters ended September 30, 2006 through June 30, 2008. The quarterly
information has been obtained from the Corporation's interim unaudited
consolidated financial statements which, in the opinion of management, have been
prepared in accordance with Canadian GAAP and as required by utility regulators.
The timing of the recognition of certain assets, liabilities, revenues and
expenses, as a result of regulation, may differ from that otherwise expected
using Canadian GAAP for non-regulated entities. The differences and nature of
regulation are disclosed in Notes 2 and 4 to the Corporation's 2007 annual
audited consolidated financial statements. The quarterly operating results are
not necessarily indicative of results for any future period and should not be
relied upon to predict future performance.
--------------------------------------------------------------------------
Fortis Inc.
Summary of Quarterly Results (Unaudited)
--------------------------------------------------------------------------
Net Earnings Earning per
Quarter Ended Revenue and Applicable to Common Share
Equity Income Common Shares Basic Diluted
($ millions) ($ millions) ($) ($)
--------------------------------------------------------------------------
June 30, 2008 848 29 0.19 0.18
--------------------------------------------------------------------------
March 31, 2008 1,146 91 0.58 0.55
--------------------------------------------------------------------------
December 31, 2007 1,018 79 0.51 0.49
--------------------------------------------------------------------------
September 30, 2007 651 31 0.20 0.20
--------------------------------------------------------------------------
June 30, 2007 566 41 0.31 0.27
--------------------------------------------------------------------------
March 31, 2007 483 42 0.38 0.35
--------------------------------------------------------------------------
December 31, 2006 393 34 0.33 0.32
--------------------------------------------------------------------------
September 30, 2006 342 39 0.37 0.36
--------------------------------------------------------------------------
A summary of the past eight quarters reflects the Corporation's continued
organic growth, growth from acquisitions, as well as the seasonality associated
with its businesses. Interim results will fluctuate due to the seasonal nature
of gas and electricity demand and water flows, as well as the timing and
recognition of regulatory decisions. Given the diversified group of companies,
seasonality may vary. Financial results from May 17, 2007 were impacted by the
acquisition of Terasen. Virtually all of the annual earnings of the Terasen Gas
companies occur in the first and fourth quarters. Financial results for the
second quarter ended June 30, 2008, reflected the $13 million unfavourable
impact to Fortis of a charge recorded at Belize Electricity as a result of the
June 2008 regulatory rate decision. Due to a shift in the quarterly
distribution of annual purchased power expense at Newfoundland Power,
Newfoundland Power's earnings in 2008 will be lower in the first and fourth
quarters and higher in the second and third quarters compared to the same
periods in 2007. Newfoundland Power's annual earnings will not be impacted by
the shift in quarterly earnings. Financial results from August 1, 2007 were
impacted by the acquisition of the Delta Regina in Saskatchewan and from
November 1, 2006 were impacted by the acquisition of four hotels in western
Canada. Financial results from August 28, 2006 were impacted by the acquisition
of Fortis Turks and Caicos, while earnings from January 1, 2007 were impacted by
the consolidation of an approximate 54 per cent controlling interest in
Caribbean Utilities. The Corporation's previous approximate 37 per cent
interest in Caribbean Utilities was accounted for on an equity basis.
June 30, 2008/June 30 2007 - Net earnings applicable to common shares were $29
million, or $0.19 per common share for the second quarter of 2008, compared to
earnings of $41 million, or $0.31 per common share, for the second quarter of
2007. Second quarter results included a $13 million, or $0.08 per common share,
charge representing the Corporation's approximate 70 per cent share of
disallowed previously incurred fuel and purchased power costs at Belize
Electricity, and included a $2 million one-time charge at FortisOntario
associated with repayment of interconnection agreement amounts received in the
fourth quarter of 2007. Excluding the above one-time items, earnings for the
second quarter were $44 million, compared to $41 million for the same quarter
last year. Earnings were favourably impacted by a full quarter of earnings'
contribution from the Terasen Gas companies, higher earnings at Newfoundland
Power associated with a shift in the quarterly distribution of annual purchased
power expense, increased non-regulated hydroelectric production and improved
performance at Fortis Properties. Partially offsetting these items were lower
earnings at FortisAlberta associated with higher corporate income taxes, and
higher corporate financing costs associated with the Terasen acquisition.
March 2008/March 2007 - Net earnings applicable to common shares were $91
million, or $0.58 per common share, for the first quarter of 2008, up $49
million from earnings of $42 million, or $0.38 per common share, for the first
quarter of 2007. Growth in earnings was primarily attributable to the
contribution from the Terasen Gas companies, acquired on May 17, 2007, and also
reflected improved performance at Caribbean Utilities. The growth was partially
offset by higher corporate financing costs associated with the Terasen
acquisition and lower earnings at Newfoundland Power associated with a shift in
the quarterly distribution of annual purchased power expense. Earnings'
contribution from Caribbean Utilities during the first quarter of 2007 was
reduced by $2 million associated with a charge on the disposal of steam-turbine
assets.
December 2007/December 2006 - Net earnings applicable to common shares were $79
million, or $0.51 per common share, for the fourth quarter of 2007 compared to
earnings of $34 million, or $0.33 per common share, for the fourth quarter of
2006. The increase in earnings was driven by the contribution from the Terasen
Gas companies, including a $7 million after-tax gain on the sale of surplus
land, partially offset by increased corporate costs driven by Terasen
acquisition-related finance charges. Fourth quarter 2007 results also included
a one-time gain at FortisOntario related to a refund received associated with an
interconnection agreement.
September 2007/September 2006 - Net earnings applicable to common shares were
$31 million, or $0.20 per common share, for the third quarter of 2007 compared
to earnings of $39 million, or $0.37 per common share, for the third quarter of
2006. A $1.15 billion Common Share issue in May 2007, to fund a significant
portion of the net cash purchase price of Terasen, combined with the seasonality
of earnings of the Terasen Gas companies, diluted earnings per common share for
the third quarter of 2007. Increased earnings' contribution from FortisAlberta,
driven by customer growth and higher corporate income tax recoveries; increased
earnings' contribution from Fortis Turks and Caicos, acquired in August 2006;
and growth at Fortis Properties from expanded hospitality operations in western
Canada were more than offset by higher finance charges associated with
acquisitions, losses at the Terasen Gas companies due to seasonality of
operations and lower non-regulated hydroelectric production due to lower
rainfall.
SUBSEQUENT EVENT
Subsequent to June 30, 2008, Terasen reached a settlement with Revenu Quebec and
Canada Revenue Agency related to amounts owing as a result of retroactive
amending Quebec tax legislation. The legislation was passed in 2006 for the
purpose of challenging certain inter-provincial Canadian tax structures. In
2006, Terasen had provided for amounts owing as a result of the retroactive
legislation. In August 2008, Terasen made a payment of approximately $16.7
million to settle the tax liability. As a result of the tax settlement, an
earnings' benefit of approximately $7.5 million is expected to be recorded
during the third quarter of 2008.
OUTLOOK
The Corporation's principal businesses of regulated gas and electricity
distribution are capital intensive. Over the next five years, the Corporation's
consolidated capital program is expected to exceed $4.5 billion, with
approximately $3.5 billion to be driven by FortisAlberta, FortisBC and the
Corporation's regulated and non-regulated electric utility operations in the
Caribbean. Gross gas utility capital expenditures are expected to exceed $1
billion. The Corporation's capital program should drive growth in earnings.
With Terasen now substantially integrated into the Fortis Group of Companies,
Fortis is well positioned to pursue acquisitions for profitable growth, focusing
on opportunities to acquire regulated natural gas and electric utilities in
Canada, the United States and the Caribbean. Fortis will also pursue growth in
its non-regulated businesses in support of its regulated utility growth
strategy.
OUTSTANDING SHARE DATA
As at August 7, 2008, the Corporation had issued and outstanding 157.1 million
Common Shares; 5.0 million First Preference Shares, Series C; 8.0 million First
Preference Shares, Series E; 5.0 million First Preference Shares, Series F; and
9.2 million First Preference Shares, Series G.
The number of Common Shares of Fortis that would be issued if all outstanding
share options, convertible debt and First Preference Shares, Series C and E were
converted as at August 7, 2008 is as follows:
--------------------------------------------------------------------------
Fortis Inc.
Conversion of Securities into Common Shares
As at August 7, 2008 (Unaudited)
--------------------------------------------------------------------------
Security Number of Common Shares (millions)
--------------------------------------------------------------------------
Stock Options 4.2
--------------------------------------------------------------------------
Convertible Debt 1.4
--------------------------------------------------------------------------
First Preference Shares, Series C 5.0
--------------------------------------------------------------------------
First Preference Shares, Series E 8.0
--------------------------------------------------------------------------
Total 18.6
--------------------------------------------------------------------------
Additional information, including the Fortis 2007 Annual Information Form,
Management Information Circular and Annual Report, is available on SEDAR at
www.sedar.com and on the Corporation's web site at www.fortisinc.com.
FORTIS INC.
Interim Consolidated Financial Statements
For the three and six months ended June 30, 2008 and 2007
(Unaudited)
Fortis Inc.
Consolidated Balance Sheets (Unaudited)
As at
(in millions of Canadian dollars)
June 30 December 31
2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
ASSETS
Current assets
Cash and cash equivalents $59 $58
Accounts receivable 736 635
Prepaid expenses 15 19
Regulatory assets (Note 6) 85 119
Inventories of gas, materials and supplies 192 207
-------------------------------------------------------------------------
1,087 1,038
Deferred charges and other assets 198 179
Regulatory assets (Note 6) 162 193
Future income taxes 39 37
Utility capital assets 6,962 6,748
Income producing properties 519 519
Intangibles, net of amortization 12 15
Goodwill 1,550 1,544
-------------------------------------------------------------------------
$10,529 $10,273
-------------------------------------------------------------------------
-------------------------------------------------------------------------
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities
Short-term borrowings (Note 18) $279 $475
Accounts payable and accrued charges 685 793
Dividends payable 42 43
Income taxes payable 59 30
Regulatory liabilities (Note 6) 245 20
Current installments of long-term debt and
capital lease obligations (Note 7) 338 436
Future income taxes 11 7
-------------------------------------------------------------------------
1,659 1,804
Deferred credits 270 261
Regulatory liabilities (Note 6) 383 372
Future income taxes 62 55
Long-term debt and capital lease obligations
(Note 7) 4,704 4,623
Non-controlling interest 116 115
Preference shares 320 320
-------------------------------------------------------------------------
7,514 7,550
-------------------------------------------------------------------------
Shareholders' equity
Common shares (Note 8) 2,148 2,126
Preference shares (Note 9) 347 122
Contributed surplus 7 6
Equity portion of convertible debentures 5 6
Accumulated other comprehensive loss (Note 11) (84) (88)
Retained earnings 592 551
-------------------------------------------------------------------------
3,015 2,723
-------------------------------------------------------------------------
$10,529 $10,273
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Contingent liabilities and commitments (Note 19)
See accompanying Notes to interim consolidated financial statements.
Fortis Inc.
Consolidated Statements of Earnings (Unaudited)
For the periods ended June 30
(in millions of Canadian dollars, except per share amounts)
Quarter Ended Six Months Ended
2008 2007 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Operating revenues $848 $566 $1,994 $1,049
-------------------------------------------------------------------------
Expenses
Energy supply costs 439 242 1,107 457
Operating 182 139 361 254
Amortization 86 65 169 119
-------------------------------------------------------------------------
707 446 1,637 830
-------------------------------------------------------------------------
Operating income 141 120 357 219
Finance charges
(Note 13) 90 67 181 115
-------------------------------------------------------------------------
Earnings before
corporate taxes and
non-controlling
interest 51 53 176 104
Corporate taxes
(Note 14) 19 6 48 13
-------------------------------------------------------------------------
Net earnings before
non-controlling
interest 32 47 128 91
Non-controlling
interest - 4 4 5
-------------------------------------------------------------------------
Net earnings 32 43 124 86
Preference share
dividends 3 2 4 3
-------------------------------------------------------------------------
Net earnings
applicable to
common shares $29 $41 $120 $83
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per common
share (Note 8)
Basic $0.19 $0.31 $0.77 $0.69
Diluted $0.18 $0.27 $0.75 $0.61
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying Notes to interim consolidated financial statements.
Fortis Inc.
Consolidated Statements of Retained Earnings (Unaudited)
For the periods ended June 30
(in millions of Canadian dollars)
Quarter Ended Six Months Ended
2008 2007 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Balance at
beginning of
period $603 $504 $551 $486
Net earnings
applicable to
common shares 29 41 120 83
-------------------------------------------------------------------------
632 545 671 569
Dividends on
common shares (40) (32) (79) (56)
-------------------------------------------------------------------------
Balance at end
of period $592 $513 $592 $513
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying Notes to interim consolidated financial statements.
Fortis Inc.
Consolidated Statements of Comprehensive Income (Unaudited)
For the periods ended June 30
(in millions of Canadian dollars)
Quarter Ended Six Months Ended
2008 2007 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Net earnings $32 $43 $124 $86
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Unrealized foreign
currency translation
(losses) gains on
net investments in
self-sustaining
foreign operations (3) (36) 13 (41)
Gains (losses) on
hedges of net
investments in
self-sustaining
foreign operations 3 19 (11) 21
Corporate tax
(expense) recovery - (4) 2 (4)
-------------------------------------------------------------------------
Change in unrealized
foreign currency
translation (losses)
gains, net of
hedging activities
and tax (Note 11) - (21) 4 (24)
-------------------------------------------------------------------------
Comprehensive
income $32 $22 $128 $62
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying Notes to interim consolidated financial statements.
Fortis Inc.
Consolidated Statements of Cash Flows (Unaudited)
For the periods ended June 30
(in millions of Canadian dollars)
Quarter Ended Six Months Ended
2008 2007 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Operating Activities
Net earnings $32 $43 $124 $86
Items not affecting
cash
Amortization -
utility capital
assets and income
producing properties 83 62 163 114
Amortization -
intangibles and
other 3 3 6 5
Future income taxes 12 1 15 -
Non-controlling
interest - 4 4 5
Write-down of
deferred power
costs - Belize
Electricity
(Note 6) 18 - 18 -
Other 1 (1) (4) 3
Change in long-term
regulatory assets
and liabilities 1 3 10 (8)
-------------------------------------------------------------------------
150 115 336 205
Change in non-cash
operating working
capital 94 (47) 96 (43)
-------------------------------------------------------------------------
244 68 432 162
-------------------------------------------------------------------------
Investing Activities
Change in deferred
charges, other
assets and deferred
credits (12) (2) (17) (3)
Utility capital
expenditures (219) (193) (381) (327)
Contributions in aid
of construction 20 18 32 39
Income-producing
property capital
expenditures (5) (3) (8) (6)
Proceeds on sale of
capital assets 1 2 16 3
Business acquisition - (1,251) - (1,253)
-------------------------------------------------------------------------
(215) (1,429) (358) (1,547)
-------------------------------------------------------------------------
Financing Activities
Change in short-term
borrowings (163) (26) (196) (70)
Proceeds from
long-term debt, net
of issue costs 409 33 659 143
Repayments of
long-term debt and
capital lease
obligations (200) (16) (205) (33)
Net (repayments)
borrowings under
committed credit
facilities (266) 300 (477) 182
Advances to
non-controlling
interest - (2) - (2)
Issue of common
shares 5 1,131 11 1,254
Issue of preference
shares 223 - 223 -
Dividends
Common shares (40) (32) (79) (56)
Preference shares (3) (2) (4) (3)
Subsidiary
dividends paid
to non-controlling
interest (2) (3) (5) (6)
-------------------------------------------------------------------------
(37) 1,383 (73) 1,409
-------------------------------------------------------------------------
Effect of exchange rate
changes on cash and
cash equivalents - (2) - (2)
-------------------------------------------------------------------------
Change in cash and cash
equivalents (8) 20 1 22
Cash and cash
equivalents, beginning
of period 67 43 58 41
-------------------------------------------------------------------------
Cash and cash
equivalents, end of
period $59 $63 $59 $63
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying Notes to interim consolidated financial statements.
FORTIS INC.
NOTES TO INTERIM CONSOLIDATED FINANCIAL STATEMENTS
For the three and six months ended June 30, 2008 and 2007 (unless otherwise
stated)
(Unaudited)
---------------------------------------------------------------------------
---------------------------------------------------------------------------
1. DESCRIPTION OF THE BUSINESS
Nature of Operations
Fortis Inc. ("Fortis" or the "Corporation") is principally an international
distribution utility holding company. Fortis segments its utility operations by
franchise area and, depending on regulatory requirements, by the nature of the
assets. Fortis also holds investments in non-regulated generation, and
commercial real estate and hotels, which are treated as two separate segments.
The Corporation's operating segments allow senior management to evaluate the
operational performance and assess the overall contribution of each segment to
the Corporation's long-term objectives. Each operating segment operates as an
autonomous unit, assumes profit and loss responsibility and is accountable for
its own resource allocation.
REGULATED UTILITIES
The following summary describes the Corporation's interests in regulated gas and
electric utilities in Canada and the Caribbean by utility:
Regulated Gas Utilities - Canadian
Terasen Gas Companies: Includes Terasen Gas Inc. ("TGI"), Terasen Gas
(Vancouver Island) Inc. ("TGVI"), and Terasen Gas (Whistler) Inc.
("TGWI"), which Fortis acquired through the acquisition of Terasen Inc.
("Terasen") on May 17, 2007.
TGI is the largest distributor of natural gas in British Columbia,
serving approximately 826,800 residential, commercial and industrial
customers in a service area that extends from Vancouver to the Fraser
Valley and the interior of British Columbia.
TGVI owns and operates the natural gas transmission pipeline from the
Greater Vancouver area across the Georgia Strait to Vancouver Island
and the distribution system on Vancouver Island and along the Sunshine
Coast of British Columbia, serving approximately 92,800 residential,
commercial and industrial customers.
In addition to providing transmission and distribution services to
customers, TGI and TGVI also obtain natural gas supplies on behalf of
most residential and commercial customers. Gas supplies are sourced
primarily from northeastern British Columbia and, through TGI's
Southern Crossing Pipeline, from Alberta.
TGWI owns and operates the propane distribution system in Whistler,
British Columbia, providing service to approximately 2,400 residential
and commercial customers.
Regulated Electric Utilities - Canadian
a. FortisAlberta: FortisAlberta owns and operates the electricity
distribution system in a substantial portion of southern and central
Alberta, serving approximately 453,500 customers.
b. FortisBC: Includes FortisBC Inc., an integrated electric utility
operating in the southern interior of British Columbia, serving
approximately 155,000 customers. FortisBC Inc. owns four hydroelectric
generating plants with a combined capacity of 223 megawatts ("MW").
Included with the FortisBC component of the Regulated Electric
Utilities - Canadian segment are the operating, maintenance and
management services relating to the 450-MW Waneta hydroelectric
generating facility owned by Teck Cominco Metals Ltd., the 149-MW
Brilliant Hydroelectric Plant owned by Columbia Power Corporation and
the Columbia Basin Trust ("CPC/CBT"), the 185-MW Arrow Lakes
Hydroelectric Plant owned by CPC/CBT and the distribution system owned
by the City of Kelowna.
c. Newfoundland Power: Newfoundland Power is the principal distributor of
electricity in Newfoundland, serving more than 233,000 customers.
Newfoundland Power has an installed generating capacity of
approximately 139 MW, of which 96 MW is hydroelectric generation.
d. Maritime Electric: Maritime Electric is the principal distributor of
electricity on Prince Edward Island, serving approximately 72,000
customers. Maritime Electric also maintains on-Island generating
facilities with a combined capacity of 150 MW.
e. FortisOntario: FortisOntario provides an integrated electric utility
service to approximately 52,000 customers in Fort Erie, Cornwall,
Gananoque and Port Colborne in Ontario. FortisOntario operations
include Canadian Niagara Power Inc. ("Canadian Niagara Power") and
Cornwall Street Railway, Light and Power Company, Limited ("Cornwall
Electric"). Included in Canadian Niagara Power's accounts is the
operation of the electricity distribution business of Port Colborne
Hydro Inc., which has been leased from the City of Port Colborne under
a 10-year lease agreement that expires in April 2012. FortisOntario
also owns a 10 per cent interest in each of Westario Power Inc. and
Rideau St. Lawrence Holdings Inc., two regional electric distribution
companies formed in 2000, serving more than 27,000 customers.
Regulated Electric Utilities - Caribbean
a. Belize Electricity: Belize Electricity is the principal distributor of
electricity in Belize, Central America, serving approximately 73,500
customers. The Company has an installed generating capacity of 36 MW.
Fortis holds an approximate 70 per cent controlling interest in Belize
Electricity.
b. Caribbean Utilities: Caribbean Utilities is the sole provider of
electricity on Grand Cayman, Cayman Islands, serving over 24,000
customers. The Company has an installed generating capacity of
approximately 137 MW. Fortis has an approximate 54 per cent
controlling ownership interest in Caribbean Utilities. Caribbean
Utilities is a public company traded on the Toronto Stock Exchange
(TSX:CUP.U) and has an April 30 fiscal year end. Fortis consolidates
Caribbean Utilities' financial statements on a two-month lag basis.
c. P.P.C. Limited and Atlantic Equipment & Power (Turks and Caicos) Ltd.
(collectively referred to as Fortis Turks and Caicos): Fortis Turks and
Caicos is the principal distributor of electricity on the Turks and
Caicos Islands, serving more than 9,000 customers. The Company has a
combined diesel-fired generating capacity of 48 MW.
Non-Regulated - Fortis Generation
a. Belize: Operations consist of the 25-MW Mollejon and 7-MW Chalillo
hydroelectric generating facilities in Belize. All of the facilities'
output is sold to Belize Electricity under a 50-year power purchase
agreement expiring in 2055. Hydroelectric generation operations in
Belize are conducted through the Corporation's wholly owned indirect
subsidiary, Belize Electric Company Limited ("BECOL"), under a
Franchise Agreement with the Government of Belize.
b. Ontario: Includes 75 MW of water-right entitlement associated with the
Niagara Exchange Agreement, which expires April 30, 2009, a 5-MW gas-
fired cogeneration plant in Cornwall and six small hydroelectric
generating stations in eastern Ontario with a combined capacity of 8
MW. Non-regulated generation operations in Ontario are conducted
through FortisOntario Inc. and Fortis Properties.
c. Central Newfoundland: Through the Exploits River Hydro Partnership
("Exploits Partnership"), a partnership between the Corporation, through
its wholly owned subsidiary Fortis Properties, and Abitibi-Consolidated
Company of Canada ("Abitibi-Consolidated"), 36 MW of additional
capacity was developed and installed at two of Abitibi-Consolidated's
hydroelectric generating plants in central Newfoundland. Fortis
Properties holds directly a 51 per cent interest in the Exploits
Partnership and Abitibi-Consolidated holds the remaining 49 per cent
interest. The Exploits Partnership sells its output to Newfoundland
and Labrador Hydro Corporation under a 30-year power purchase agreement
expiring in 2033.
d. British Columbia: Includes the 16-MW run-of-river Walden hydroelectric
power plant near Lillooet, British Columbia. This plant sells its
entire output to BC Hydro under a long-term contract expiring in 2013.
Hydroelectric generation operations in British Columbia are conducted
through the Walden Power Partnership, a wholly owned partnership of
FortisBC Inc.
e. Upper New York State: Includes the operations of four hydroelectric
generating stations in Upper New York State, with a combined capacity
of approximately 23 MW, operating under licences from the US Federal
Energy Regulatory Commission ("FERC"). Hydroelectric generation
operations in Upper New York State are conducted through the
Corporation's indirect wholly owned subsidiary, FortisUS Energy
Corporation.
Non-Regulated - Fortis Properties
Fortis Properties owns and operates 19 hotels with more than 3,500 rooms in
eight Canadian provinces and approximately 2.8 million square feet of commercial
real estate primarily in Atlantic Canada.
Corporate and Other
The Corporate and Other segment captures expense and revenue items not
specifically related to any reportable segment. Included in this segment are
finance charges including interest on debt incurred directly by Fortis and
Terasen Inc. and dividends on preference shares classified as long-term
liabilities; dividends on preference shares classified as equity; other
corporate expenses, including Fortis and Terasen corporate operating costs, net
of recoveries from subsidiaries; interest and miscellaneous revenues; and
corporate income taxes. Also included in the Corporate and Other segment are the
financial results of CustomerWorks Limited Partnership ("CWLP"). CWLP is a
non-regulated shared-services business in which Terasen holds a 30 per cent
interest. CWLP operates in partnership with Enbridge Inc. and provides customer
service contact, meter reading, billing, credit, support and collection services
to the Terasen Gas companies and several smaller third parties. CWLP's
financial results are recorded using the proportionate consolidation method of
accounting. While currently not significant, financial results of Terasen
Energy Services Inc. ("TES") are also reported in the Corporate and Other
segment. TES is a non-regulated wholly owned subsidiary of Terasen. TES
expects to increase its activities in the development, building, owning and
operating of innovative geoexchange energy systems, community piping and energy
transfer systems to harness renewable energy sources. TES is entering into
agreements with developers to provide alternative thermal energy systems for
both residential and commercial development projects in British Columbia.
2. BASIS OF PRESENTATION
These interim consolidated financial statements have been prepared in accordance
with Canadian generally accepted accounting principles ("Canadian GAAP") for
interim financial statements and do not include all of the disclosures normally
found in the Corporation's Annual Consolidated Financial Statements. These
interim consolidated financial statements should be read in conjunction with the
Corporation's 2007 Annual Consolidated Financial Statements. Interim results
will fluctuate due to the seasonal nature of gas and electricity demand and
water flows as well as the timing and recognition of regulatory decisions.
Virtually all of the annual earnings of the Terasen Gas companies occur in the
first and fourth quarters due to seasonality of the business. Given the
diversified group of companies, seasonality may vary.
3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
These interim consolidated financial statements have been prepared in accordance
with Canadian GAAP, including selected accounting treatments that differ from
those used by entities not subject to rate regulation. The timing of the
recognition of certain assets, liabilities, revenues and expenses, as a result
of regulation, may differ from that otherwise expected using Canadian GAAP for
entities not subject to rate regulation. The differences and nature of
regulation are disclosed in Notes 2 and 4 to the Corporation's 2007 Annual
Consolidated Financial Statements. These interim consolidated financial
statements have been prepared following the same accounting policies and methods
as those used in preparing the Corporation's 2007 Annual Consolidated Financial
Statements except as described below. All amounts are presented in Canadian
dollars unless otherwise stated.
Effective January 1, 2008, the Corporation adopted the following new accounting
standards issued by the Canadian Institute of Chartered Accountants ("CICA").
Inventories
Section 3031, Inventories, requires inventories to be measured at the lower of
cost or net realizable value; disallows the use of a last-in first-out
inventory-costing methodology; and requires that, when circumstances which
previously caused inventories to be written down below cost or net realizable
value no longer exist, the amount of the write-down is to be reversed. As at
December 31, 2007, inventories of $26 million were reclassified to property,
plant and equipment from inventory on the balance sheet as they are held for the
development, construction, maintenance and repair of other property, plant and
equipment. These inventories will be amortized using the straight-line method
based on estimated service lives of the capital assets to which they are added
when put in service. During the three and six months ended June 30, 2008,
inventories of $256 million and $693 million, respectively, were expensed and
reported in energy supply costs in the consolidated statement of earnings ($170
million for the three and six months ended June 30, 2007). Inventories expensed
to operating expenses were $1.5 million and $2.5 million for the three and six
months ended June 30, 2008, respectively ($1.6 million and $2.5 million for the
three and six months ended June 30, 2007, respectively).
Capital Disclosures
Section 1535, Capital Disclosures, requires the Corporation to disclose
additional information about its capital and the manner in which it is managed.
The additional disclosure includes quantitative and qualitative information
regarding the Corporation's objectives, policies and processes for managing
capital. The new disclosures are provided in Note 16.
Disclosure and Presentation of Financial Instruments
Section 3862, Financial Instruments - Disclosures, and Section 3863, Financial
Instruments - Presentation, require disclosures of both qualitative and
quantitative information that enables users of financial statements to evaluate
the nature and extent of risks from financial instruments to which the
Corporation is exposed. The new disclosures are provided in Notes 17 and 18.
4. FUTURE ACCOUNTING POLICIES
International Financial Reporting Standards ("IFRS")
In February 2008, the Accounting Standards Board ("AcSB") confirmed that the use
of IFRS will be required in 2011 for publicly accountable enterprises in Canada.
In April 2008, the AcSB issued an IFRS Omnibus Exposure Draft proposing that
publicly accountable enterprises be required to apply IFRS, in full and without
modification, on January 1, 2011. The transition date of January 1, 2011 will
require the restatement, for comparative purposes, of amounts reported by the
Corporation for its year ended December 31, 2010, and of the opening balance
sheet as at January 1, 2010. The AcSB proposes that CICA Handbook Section -
Accounting Changes, paragraph 1506.30, which would require an entity to disclose
information relating to a new primary source of GAAP that has been issued but is
not yet effective and that the entity has not applied, not be applied with
respect to this Exposure Draft. Fortis is continuing to assess the financial
reporting impacts of the adoption of IFRS and, at this time, the impact on
future financial position and results of operations is not reasonably
determinable or estimable. Further, Fortis anticipates a significant increase
in disclosure resulting from the adoption of IFRS and is continuing to assess
the level of disclosure required and any necessary system changes to gather and
process the information.
Rate-Regulated Operations
In March 2007, the AcSB issued an Exposure Draft on rate-regulated operations
that proposed: (i) the temporary exemption in Section 1100, Generally Accepted
Accounting Principles, of the CICA Handbook providing relief to entities subject
to rate regulation from the requirement to apply the Section to the recognition
and measurement of assets and liabilities arising from rate regulation be
removed; (ii) the explicit guidance for rate-regulated operations provided in
Section 1600, Consolidated Financial Statements, Section 3061, Property, Plant
and Equipment, Section 3465, Income Taxes, and Section 3475, Disposal of
Long-Lived Assets and Discontinued Operations, be removed; and (iii) Accounting
Guideline 19, Disclosures by Entities Subject to Rate Regulation ("AcG-19"), be
retained as is.
In August 2007, the AcSB issued a Decision Summary on the Exposure Draft that
supported the removal of the temporary exemption in Section 1100, Generally
Accepted Accounting Principles, and the amendment to Section 3465, Income Taxes,
to recognize future income tax liabilities and assets as well as offsetting
regulatory assets and liabilities by entities subject to rate regulation. Both
changes will apply prospectively for fiscal years beginning on or after January
1, 2009. The AcSB also decided that the current guidance for rate-regulated
operations pertaining to property, plant and equipment, disposal of long-lived
assets and discontinued operations, and consolidated financial statements be
maintained, and that the existing AcG-19 will not be withdrawn from the CICA
Handbook but that the guidance will be updated as a result of the other changes.
The AcSB also decided that the final Background Information and Basis for
Conclusions associated with its rate-regulation project would not express any
views of the AcSB regarding the status of US Statement of Financial Accounting
Standards No. 71, Accounting for the Effects of Certain Types of Regulation, as
"another source of GAAP" within the Canadian GAAP hierarchy.
Effective January 1, 2009, the impact on Fortis of the amendment to Section
3465, Income Taxes, will be the recognition of future income tax assets and
liabilities and related regulatory liabilities and assets for the amount of
future income taxes expected to be refunded to, or recovered from, customers in
future gas and electricity rates. Currently, the Terasen Gas companies,
FortisAlberta, FortisBC and Newfoundland Power use the taxes payable method of
accounting for income taxes. The effect on the Corporation's interim
consolidated financial statements, if it had adopted amended Section 3465,
Income Taxes, as at June 30, 2008, would have been an increase in future income
tax assets and future income tax liabilities of $37 million and $465 million,
respectively, and a corresponding increase in regulatory liabilities and
regulatory assets of $37 million and $465 million, respectively. Included in
the amounts are the future income tax effects of the subsequent settlement of
the related regulatory assets and liabilities through customer rates, and the
separate disclosure of future income tax assets and liabilities that are
currently not recognized. Fortis is continuing to assess and monitor any
additional implications on its financial reporting related to accounting for
rate-regulated operations.
Goodwill and Intangible Assets
Effective January 1, 2009, the Corporation will be adopting the new CICA
Handbook Section 3064 - Goodwill and Intangible Assets. This Section, which
replaces Section 3062, Goodwill and Other Intangible Assets, and Section 3450,
Research and Development Costs, establishes standards for the recognition,
measurement and disclosure of goodwill and intangible assets. The provisions
related to the definition and initial recognition of intangible assets,
including internally generated intangible assets, are equivalent to the
corresponding provisions of International Accounting Standard 38, Intangible
Assets. The Corporation is continuing to assess the financial reporting impact
of adopting this standard.
5. USE OF ESTIMATES
The preparation of the Corporation's interim consolidated financial statements
in accordance with Canadian GAAP requires management to make estimates and
judgments that affect the reported amounts of assets and liabilities and the
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenue and expenses during the reporting
periods. Estimates and judgments are based on historical experience, current
conditions and various other assumptions believed to be reasonable under the
circumstances.
Additionally, certain estimates are necessary since the regulatory environments
in which the Corporation's utilities operate often require amounts to be
recorded at estimated values until these amounts are finalized pursuant to
regulatory decisions or other regulatory proceedings. Due to changes in facts
and circumstances and the inherent uncertainty involved in making estimates,
actual results may differ significantly from current estimates. Estimates and
judgments are reviewed periodically and, as adjustments become necessary, are
reported in earnings in the period they become known.
Interim financial statements may also employ a greater use of estimates than the
annual financial statements. There were no material changes to the Corporation's
critical accounting estimates during the six months ended June 30, 2008 from
those disclosed in the Corporation's Management Discussion and Analysis for the
year ended December 31, 2007.
6. REGULATORY ASSETS AND LIABILITIES
A summary of the Corporation's regulatory assets and liabilities is provided
below. A description of the nature of the regulatory assets and liabilities is
provided in Note 4 to the Corporation's 2007 Annual Audited Consolidated
Financial Statements.
As at As at
June 30, December 31,
($ millions) 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Regulatory Assets
Rate stabilization accounts - Terasen Gas
companies (1) 11 99
Rate stabilization accounts - electric utilities (2) 67 55
Regulatory other post-employment benefit ("OPEB")
asset 48 44
Income taxes recoverable on OPEB plans 17 16
Alberta Electric System Operator ("AESO") charges
deferral 20 8
Deferred capital asset amortization 10 12
Weather normalization account 8 11
Residential unbundling 7 9
Deferred pension costs 8 8
Southern Crossing Pipeline tax reassessment 7 7
Energy management costs 7 6
Lease costs 5 5
Other regulatory assets 32 32
-------------------------------------------------------------------------
Total regulatory assets 247 312
Less: current portion (85) (119)
-------------------------------------------------------------------------
Long-term regulatory assets 162 193
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Regulatory Liabilities
Rate stabilization accounts - Terasen Gas
companies (3) 227 -
Future removal and site restoration provision 332 319
Unbilled revenue liability 19 22
Pension deferral 5 6
Performance-based rate-setting incentive liabilities 14 14
Other regulatory liabilities 31 31
-------------------------------------------------------------------------
Total regulatory liabilities 628 392
Less: current portion (245) (20)
-------------------------------------------------------------------------
Long-term regulatory liabilities 383 372
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) Rate stabilization asset accounts include the revenue deficiency
deferral account and revenue stabilization adjustment mechanism
account. At December 31, 2007, the rate stabilization accounts also
included the midstream cost reconciliation account ("MCRA"), commodity
cost reconciliation account ("CCRA") and gas cost variance account
("GCVA"). The decrease in the rate stabilization asset accounts from
December 31, 2007 was mainly due to the shift in the MCRA and CCRA to
payable balances at June 30, 2008 from receivable balances at December
31, 2007 as a result of recording the change in the fair market value
of the natural gas derivative contracts, which were in the money at
June 30, 2008 versus out of the money at December 31, 2007.
(2) During the three months ended June 30, 2008, a downward $18 million
adjustment was made to Belize Electricity's cost of power rate
stabilization account reflecting, in substance, the disallowance of
previously incurred fuel and purchased power costs as a result of the
Final Decision by the Public Utilities Commission ("PUC") of Belize on
Belize Electricity's 2008/2009 rate application. Belize Electricity
filed an application for judicial review and appeal of the Final
Decision with the Supreme Court of Belize on July 25, 2008.
(3) Rate stabilization liability accounts include the MCRA, CCRA and GCVA.
7. LONG-TERM DEBT AND CAPITAL LEASE OBLIGATIONS
As at As at
June 30, December 31,
($ millions) 2008 2007
------------------------------------------------------------------------
------------------------------------------------------------------------
Long-term debt and capital lease obligations 5,024 4,562
Long-term classification of committed credit
facilities (Note 18) 54 530
Deferred debt financing costs (36) (33)
------------------------------------------------------------------------
Total long-term debt and capital lease obligations 5,042 5,059
Less: Current installments of long-term debt and
capital lease obligations (338) (436)
------------------------------------------------------------------------
4,704 4,623
------------------------------------------------------------------------
------------------------------------------------------------------------
In February 2008, TGVI issued $250 million 6.05% senior unsecured debentures,
maturing in February 2038. The net proceeds of the debenture offering were used
to repay committed credit-facility borrowings.
In April 2008, Maritime Electric issued $60 million 6.05% secured first mortgage
bonds, maturing in April 2038. The net proceeds were used to repay short-term
borrowings.
In April 2008, FortisAlberta issued $100 million 5.85% senior unsecured
debentures, maturing in April 2038. The net proceeds were used to repay
committed credit-facility borrowings.
In May 2008, TGI issued $250 million 5.80% senior unsecured debentures, maturing
in May 2038. The net proceeds of the debenture offering were primarily used to
repay maturing $188 million 6.20% debentures and short-term borrowings.
As at June 30, 2008, current installments of long-term debt and capital lease
obligations included $10 million at Belize Electricity which was reclassified
from long-term debt resulting from the default with certain debt covenants and
where waivers of the default have not yet been obtained from the lenders (Note
16).
8. COMMON SHARES
Authorized: an unlimited number of Common Shares without nominal or par value.
As at As at
June 30, December 31,
Issued and Outstanding 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Number Number
of Shares Amount of Shares Amount
(in thousands) ($ millions) (in thousands) ($ millions)
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Common Shares 157,071 2,148 155,521 2,126
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Common Shares issued during the period were as follows:
Quarter Ended June 30, 2008 Year-to-Date June 30, 2008
Number Number
of Shares Amount of Shares Amount
(in thousands) ($ millions) (in thousands) ($ millions)
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Opening balance 156,754 2,142 155,521 2,126
Conversion of
debentures 84 1 1,042 11
Consumer Share
Purchase Plan 23 - 43 1
Dividend
Reinvestment Plan 59 2 112 3
Employee Share
Purchase Plan 50 1 157 4
Stock Option Plans 101 2 196 3
-------------------------------------------------------------------------
Ending balance 157,071 2,148 157,071 2,148
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per Common Share
During the six months ended June 30, 2008, holders of the Corporation's 6.75%
and 5.50% unsecured subordinated convertible debentures converted approximately
US$11 million of the debentures into 1,041,871 Common Shares of the Corporation.
The Corporation calculates earnings per common share on the weighted average
number of common shares outstanding. The weighted average number of common
shares outstanding was 157.0 million and 131.1 million for the quarters ended
June 30, 2008 and June 30, 2007, respectively, and 156.8 million and 120.2
million for year-to-date June 30, 2008 and June 30, 2007, respectively.
Diluted earnings per common share are calculated using the treasury stock method
for options and the "if-converted" method for convertible securities.
Earnings per common share are as follows:
Quarter Ended June 30
--------------------------------------------------------------------------
--------------------------------------------------------------------------
2008 2007
--------------------------------------------------------------------------
Weighted Weighted
Average Earnings Average Earnings
Earnings Shares per Earnings Shares per
($ (in Common ($ (in Common
millions) millions) Share millions) millions) Share
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Net earnings
applicable to
common shares 29 41
Weighted average
shares
outstanding 157.0 131.1
--------------------------------------------------------------------------
Basic Earnings per
Common Share $0.19 $0.31
--------------------------------------------------------------------------
Effect of dilutive
securities:
Subscription
receipts (1) - - - 22.9
Stock options - 1.1 - 1.4
Preference shares 4 12.9 4 11.4
Convertible
debentures 1 1.4 1 3.2
--------------------------------------------------------------------------
34 172.4 46 170.0
Deduct anti-dilutive
impacts: - -
Preference shares (4) (12.9) - -
Convertible
debentures (1) (1.4) - -
--------------------------------------------------------------------------
Diluted Earnings
per Common Share 29 158.1 $0.18 46 170.0 $0.27
--------------------------------------------------------------------------
--------------------------------------------------------------------------
(1) Dilution relates to the period the Subscription Receipts were
outstanding. The Subscription Receipts were outstanding from March 15,
2007 to May 16, 2007 and were converted into Common Shares on May 17,
2007.
Earnings per Common Share
Year-to-date June 30
--------------------------------------------------------------------------
--------------------------------------------------------------------------
2008 2007
--------------------------------------------------------------------------
Weighted Weighted
Average Earnings Average Earnings
Earnings Shares per Earnings Shares per
($ (in Common ($ (in Common
millions) millions) Share millions) millions) Share
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Net earnings
applicable to
common shares 120 83
Weighted average
shares
outstanding 156.8 120.2
--------------------------------------------------------------------------
Basic Earnings per
Common Share $0.77 $0.69
--------------------------------------------------------------------------
Effect of dilutive
securities:
Subscription
receipts (1) - - - 15.7
Stock options - 1.1 - 1.4
Preference shares 8 12.9 8 11.5
Convertible
debentures 1 1.6 2 3.2
--------------------------------------------------------------------------
Diluted Earnings
per Common Share 129 172.4 $0.75 93 152.0 $0.61
--------------------------------------------------------------------------
--------------------------------------------------------------------------
(1) Dilution relates to the period the Subscription Receipts were
outstanding. The Subscription Receipts were outstanding from March 15,
2007 to May 16, 2007 and were converted into Common Shares on May 17,
2007.
9. PREFERENCE SHARES
On May 23, 2008, the Corporation issued 8 million 5.25% Five-Year Fixed Rate
Reset First Preference Shares, Series G ("First Preference Shares, Series G")
and on June 4, 2008 issued an additional 1.2 million First Preference Shares,
Series G, following the exercise in full of an over-allotment option in
connection with the offering of the 8 million of First Preference Shares, Series
G. The 9.2 million First Preference Shares, Series G were issued, at $25.00 per
share, for net after-tax proceeds of $225 million.
The holders of the First Preference Shares, Series G are entitled to receive
fixed cumulative preferential cash dividends in the amount of $1.3125 per share
per annum for each year up to and including August 31, 2013. For each five-year
period after this date, the holders of First Preference Shares, Series G are
entitled to receive fixed cumulative preferential cash dividends in the amount
per share per annum determined by multiplying the $25.00 per share by the annual
fixed dividend rate, which is the sum of the five-year Government of Canada Bond
Yield on the applicable date plus 2.13 per cent.
On September 1, 2013, and on September 1 every five years thereafter, the
Corporation may, at its option redeem for cash all or any part of the
outstanding First Preference Shares, Series G by the payment of $25.00 per share
plus all accrued and unpaid dividends.
As the First Preference Shares, Series G are not redeemable at the option of the
shareholder, they are classified as equity and the associated dividends are
deducted on the income statement immediately before arriving at net earnings
applicable to common shares.
10. STOCK-BASED COMPENSATION PLANS
In February 2008, the Corporation granted 827,504 options on Common Shares under
its 2006 Stock Option Plan at the five-day volume weighted average trading price
immediately preceding the date of grant of $28.27. The options vest evenly over
a four-year period on each anniversary of the date of grant. The options expire
seven years after the date of grant. The fair value of each option granted,
estimated using the Black-Scholes fair value option-pricing model, was $4.76 per
option.
In March 2008, 18,019 Performance Share Units ("PSUs"), formerly named
Restricted Share Units, were paid out to the President and CEO of the
Corporation at $28.36 per PSU, for a total of approximately $0.5 million. The
payout was made upon the three-year maturation period in respect of the PSU
grant which was made in March 2005 and the President and CEO satisfying the
payment requirements, as determined by the Human Resources Committee of the
Board of Directors of Fortis.
In February 2008, 32,940 PSUs were granted to the President and CEO of the
Corporation, which will mature in February 2011.
During the six months ended June 30, 2008, 27,223 Deferred Share Units were
granted to the Corporation's directors representing the equity component of
their annual compensation and their annual retainers in lieu of cash.
At June 30, 2008, 4.3 million stock options were outstanding and 2.4 million
stock options were vested.
11. ACCUMULATED OTHER COMPREHENSIVE LOSS
Accumulated other comprehensive loss includes unrealized foreign currency
translation gains and losses, net of hedging activities, gains and losses on
cash flow hedging activities and gains and losses on discontinued cash flow
hedging activities.
Quarter 2008 Quarter 2007
--------------------------------------------------------------------------
Opening Ending Opening Ending
balance Net balance balance Net balance
($ millions) April 1 change June 30 April 1 change June 30
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Unrealized foreign
currency translation
losses on net
investments in
self-sustaining
foreign operations,
net of after-tax
hedging activities (78) - (78) (54) (21) (75)
Losses on derivative
financial instruments
designated as cash
flow hedges, net of tax (1) - (1) (1) - (1)
Net losses on derivative
financial instruments
previously discontinued
as cash flow hedges, net
of tax (5) - (5) (5) - (5)
--------------------------------------------------------------------------
Accumulated Other
Comprehensive Loss (84) - (84) (60) (21) (81)
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Year-to-date 2008 Year-to-date 2007
--------------------------------------------------------------------------
Opening Ending Opening Transition Ending
balance Net balance balance amount Net balance
($ millions) January 1 change June 30 January 1 January 1 change June 30
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Unrealized
foreign currency
translation
(losses) gains
on net
investments in
self-sustaining
foreign operations,
net of after-tax
hedging activities (82) 4 (78) (51) - (24) (75)
Losses on derivative
financial
instruments
designated as cash
flow hedges, net
of tax (1) - (1) - (1) - (1)
Net losses on
derivative
financial
instruments
previously
discontinued as
cash flow hedges,
net of tax (5) - (5) - (5) - (5)
--------------------------------------------------------------------------
Accumulated Other
Comprehensive Loss (88) 4 (84) (51) (6) (24) (81)
--------------------------------------------------------------------------
--------------------------------------------------------------------------
12. EMPLOYEE FUTURE BENEFITS
The Corporation and each of its subsidiaries maintain one or more defined
benefit pension plans, defined contribution pension plans and group registered
retirement savings plans ("RRSPs") for their employees. The cost of providing
the defined benefit arrangements was $7 million for the quarter ended June 30,
2008 ($7 million for the quarter ended June 31, 2007) and $14 million
year-to-date June 30, 2008 ($11 million year-to-date June 30, 2007). The cost
of providing the defined contribution arrangements and group RRSPs for the
quarter ended June 30, 2008 was $2 million ($2 million for the quarter ended
June 30, 2007) and $5 million year-to-date June 30, 2008 ($5 million
year-to-date June 30, 2007).
13. FINANCE CHARGES
Quarter Ended Year-to-date
June 30 June 30
($ millions) 2008 2007 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Interest
- Long-term debt and
capital lease
obligations 84 60 165 104
- Short-term
borrowings 4 6 13 8
Interest charged to
construction (2) (2) (4) (3)
Interest earned - (1) (1) (2)
Dividends on preference
shares classified as
debt 4 4 8 8
-------------------------------------------------------------------------
90 67 181 115
-------------------------------------------------------------------------
-------------------------------------------------------------------------
14. CORPORATE TAXES
Corporate taxes differ from the amount that would be expected to be generated by
applying the enacted Canadian federal and provincial statutory tax rates to
earnings before corporate taxes and non-controlling interest. The following is
a reconciliation of consolidated statutory taxes to consolidated effective
taxes:
Quarter Ended June 30
2008 2007
-------------------------------------------------------------------------
(millions) % (millions) %
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Statutory taxes $16 31.2 $18 35.0
Preference share
dividends 2 4.5 2 2.8
Differences between
Canadian statutory
rates and those
applicable to foreign
subsidiaries (1) 1 2.9 (4) (8.1)
Items capitalized for
accounting but expensed
for income tax purposes (6) (11.7) (10) (19.1)
Difference between
capital cost allowance
("CCA") and other
deductions claimed for
income tax purposes, and
amounts recorded for
accounting purposes (2) 4 8.8 1 1.5
Regulatory deferrals at
Newfoundland Power 1 0.8 - -
Change in revenue
recognition policy at
Newfoundland Power - 0.1 1 0.9
Pension costs - (0.4) (1) (0.8)
Other 1 1.1 (1) (0.9)
-------------------------------------------------------------------------
Effective taxes $19 37.3 $6 11.3
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Year-to-date June 30
2008 2007
-------------------------------------------------------------------------
(millions) % (millions) %
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Statutory taxes $56 31.7 $36 35.0
Preference share
dividends 4 2.4 3 2.9
Differences between
Canadian statutory
rates and those
applicable to foreign
subsidiaries (1) (2) (1.3) (7) (6.7)
Items capitalized for
accounting but expensed
for income tax purposes (16) (9.1) (13) (13.1)
Difference between
capital cost allowance
("CCA") and other
deductions claimed for
income tax purposes,
and amounts recorded
for accounting
purposes (2) 5 2.7 (5) (4.9)
Regulatory deferrals
at Newfoundland Power 1 0.4 - -
Change in revenue
recognition policy
at Newfoundland Power - - 1 1.1
Pension costs (1) (0.6) (1) (0.8)
Other 1 1.1 (1) (1.0)
-------------------------------------------------------------------------
Effective taxes $48 27.3 $13 12.5
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) Net losses at Belize Electricity during the three and six months ended
June 30, 2008, as a result of a $13 million charge during the second
quarter of 2008 representing the Corporation's approximate 70 per cent
share of disallowed previously incurred fuel and purchased power costs,
had the effect of increasing effective corporate taxes during the three
and six months ended June 30, 2008 compared to the same periods last
year.
(2) The increase in the effective tax rate quarter over quarter and year to
date compared to the same period last year was driven by FortisAlberta.
During the three and six months ended June 30, 2008, CCA deductions at
FortisAlberta were lower than amortization expense. However, during
the same periods last year, CCA deductions at FortisAlberta were higher
than amortization expense. The higher CCA deductions last year were
required to offset taxable income expected upon the sale, in 2007, of
the 2006 AESO charges deferral receivable balance.
15. SEGMENTED INFORMATION
Information by reportable segment is as follows:
FORTIS INC.
NOTES TO INTERIM CONSOLIDATED FINANCIAL STATEMENTS
For the three and six months ended June 30, 2008 and 2007
(unless otherwise stated) (Unaudited)
--------------------------------------------------------------------------
--------------------------------------------------------------------------
15. SEGMENTED INFORMATION
Information by reportable segment is as follows:
--------------------------------------------------------------------------
REGULATED
--------------------------------------------------------------------------
Gas
Utilities Electric Utilities
---------------------- --------------------------------------------------
Quarter
ended Terasen
June 30, Gas Total
2008 Companies- Fortis Fortis NF Other Electric Electric
($ millions) Canadian Alberta BC Power Canadian Canadian Caribbean
(1) (2) (3)
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 390 75 53 120 61 309 78
Energy
supply
costs 256 - 12 70 40 122 64
Operating
expenses 62 32 17 13 7 69 12
Amortization 25 21 8 12 5 46 8
--------------------------------------------------------------------------
Operating
income 47 22 16 25 9 72 (6)
Finance
charges 30 11 7 9 5 32 2
Corporate
taxes
(recoveries) 5 4 2 6 2 14 (1)
Non-controlling
interest - - - - - - (2)
--------------------------------------------------------------------------
Net
earnings
(loss) 12 7 7 10 2 26 (5)
Preference
share
dividends - - - - - - -
--------------------------------------------------------------------------
Net
earnings
(loss)
applicable
to common
shares 12 7 7 10 2 26 (5)
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill 909 227 221 - 63 511 130
Identifiable
assets 3,587 1,414 933 983 501 3,831 683
--------------------------------------------------------------------------
Total
assets 4,496 1,641 1,154 983 564 4,342 813
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross
capital
expenditures 56 81 26 17 10 134 23
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Quarter ended
June 30, 2007
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 130 68 52 115 65 300 74
Energy
supply
costs 73 - 13 74 43 130 41
Operating
expenses 28 30 17 13 7 67 11
Amortization 12 19 8 9 4 40 7
--------------------------------------------------------------------------
Operating
income 17 19 14 19 11 63 15
Finance
charges 15 9 6 8 5 28 3
Corporate
taxes
(recoveries) 1 (5) 2 3 2 2 1
Non-controlling
interest - - - - - - 3
--------------------------------------------------------------------------
Net
earnings
(loss) 1 15 6 8 4 33 8
Preference
share
dividends - - - - - - -
--------------------------------------------------------------------------
Net
earnings
(loss)
applicable
to common
shares 1 15 6 8 4 33 8
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill 907 227 221 - 63 511 136
Identifiable
assets 3,305 1,230 850 947 457 3,484 652
--------------------------------------------------------------------------
Total
assets 4,212 1,457 1,071 947 520 3,995 788
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross
capital
expenditures 14 74 41 20 8 143 29
--------------------------------------------------------------------------
--------------------------------------------------------------------------
--------------------------------------------------------------------------
NON-REGULATED
--------------------------------------------------------------------------
Quarter ended Corporate Inter-
June 30, 2008 Fortis Fortis and segment
($ millions) Generation Properties Other eliminations Consolidated
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 22 54 5 (10) 848
Energy supply
costs 2 - - (5) 439
Operating
expenses 4 35 3 (3) 182
Amortization 3 3 1 - 86
--------------------------------------------------------------------------
Operating
income 13 16 1 (2) 141
Finance charges 2 6 20 (2) 90
Corporate taxes
(recoveries) 2 3 (4) - 19
Non-controlling
interest 2 - - - -
--------------------------------------------------------------------------
Net earnings
(loss) 7 7 (15) - 32
Preference share
dividends - - 3 - 3
--------------------------------------------------------------------------
Net earnings
(loss)
applicable to
common shares 7 7 (18) - 29
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill - - - - 1,550
Identifiable
assets 239 539 116 (16) 8,979
--------------------------------------------------------------------------
Total assets 239 539 116 (16) 10,529
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross capital
expenditures 4 5 2 - 224
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Quarter ended
June 30, 2007
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 18 47 4 (7) 566
Energy supply
costs 2 - - (4) 242
Operating
expenses 4 29 1 (1) 139
Amortization 2 3 1 - 65
--------------------------------------------------------------------------
Operating
income 10 15 2 (2) 120
Finance charges 2 6 15 (2) 67
Corporate taxes
(recoveries) 2 3 (3) - 6
Non-controlling
interest 1 - - - 4
--------------------------------------------------------------------------
Net earnings
(loss) 5 6 (10) - 43
Preference share
dividends - - 2 - 2
--------------------------------------------------------------------------
Net earnings
(loss)
applicable to
common shares 5 6 (12) - 41
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill - - - - 1,554
Identifiable
assets 235 492 128 (19) 8,277
--------------------------------------------------------------------------
Total assets 235 492 128 (19) 9,831
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross capital
expenditures 7 3 - - 196
--------------------------------------------------------------------------
--------------------------------------------------------------------------
--------------------------------------------------------------------------
REGULATED
--------------------------------------------------------------------------
Gas
Utilities Electric Utilities
--------------------------------------------------------------------------
Year-to-
date Terasen
June 30, Gas Total
2008 Companies- Fortis Fortis NF Other Electric Electric
($ millions) Canadian Alberta BC Power Canadian Canadian Caribbean
(1) (2) (3)
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 1,025 148 119 284 131 682 153
Energy
supply
costs 693 - 33 192 89 314 104
Operating
expenses 123 65 33 27 14 139 23
Amortization 49 41 17 22 9 89 15
--------------------------------------------------------------------------
Operating
income 160 42 36 43 19 140 11
Finance
charges 63 20 14 17 9 60 7
Corporate
taxes
(recoveries) 27 4 3 10 4 21 -
Non-controlling
interest - - - - - - 2
--------------------------------------------------------------------------
Net
earnings
(loss) 70 18 19 16 6 59 2
Preference
share
dividends - - - - - - -
--------------------------------------------------------------------------
Net
earnings
(loss)
applicable
to common
shares 70 18 19 16 6 59 2
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill 909 227 221 - 63 511 130
Identifiable
assets 3,587 1,414 933 983 501 3,831 683
--------------------------------------------------------------------------
Total
assets 4,496 1,641 1,154 983 564 4,342 813
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross
capital
expenditures 96 144 50 30 17 241 34
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Year-to-date
June 30, 2007
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 130 132 115 269 135 651 151
Energy
supply
costs 73 - 33 180 91 304 85
Operating
expenses 28 59 33 27 14 133 28
Amortization 12 37 16 19 8 80 14
--------------------------------------------------------------------------
Operating
income 17 36 33 43 22 134 24
Finance
charges 15 18 12 16 9 55 7
Corporate
taxes
(recoveries) 1 (9) 3 8 5 7 1
Non-controlling
interest - - - - - - 4
--------------------------------------------------------------------------
Net
earnings
(loss) 1 27 18 19 8 72 12
Preference
share
dividends - - - - - - -
--------------------------------------------------------------------------
Net
earnings
(loss)
applicable
to common
shares 1 27 18 19 8 72 12
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill 907 227 221 - 63 511 136
Identifiable
assets 3,305 1,230 850 947 457 3,484 652
--------------------------------------------------------------------------
Total
assets 4,212 1,457 1,071 947 520 3,995 788
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross
capital
expenditures 14 139 72 32 15 258 47
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Corporate Inter-
Year-to-date Fortis Fortis and segment
June 30, 2007 Generation Properties Other eliminations Consolidated
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 41 99 12 (18) 1,994
Energy
supply costs 4 - - (8) 1,107
Operating
expenses 8 66 6 (4) 361
Amortization 5 7 4 - 169
--------------------------------------------------------------------------
Operating
income 24 26 2 (6) 357
Finance charges 4 12 41 (6) 181
Corporate taxes
(recoveries) 5 4 (9) - 48
Non-controlling
interest 2 - - - 4
--------------------------------------------------------------------------
Net earnings
(loss) 13 10 (30) - 124
Preference
share
dividends - - 4 - 4
--------------------------------------------------------------------------
Net earnings
(loss)
applicable to
common shares 13 10 (34) - 120
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill - - - - 1,550
Identifiable
assets 239 539 116 (16) 8,979
--------------------------------------------------------------------------
Total assets 239 539 116 (16) 10,529
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross capital
expenditures 7 8 3 - 389
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Year-to-date
June 30, 2007
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Operating
revenues 39 87 8 (17) 1,049
Energy supply
costs 4 - - (9) 457
Operating
expenses 8 57 3 (3) 254
Amortization 5 6 2 - 119
--------------------------------------------------------------------------
Operating
income 22 24 3 (5) 219
Finance charges 5 12 26 (5) 115
Corporate taxes
(recoveries) 4 4 (4) - 13
Non-controlling
interest 1 - - - 5
--------------------------------------------------------------------------
Net earnings
(loss) 12 8 (19) - 86
Preference
share
dividends - - 3 - 3
--------------------------------------------------------------------------
Net earnings
(loss)
applicable to
common shares 12 8 (22) - 83
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Goodwill - - - - 1,554
Identifiable
assets 235 492 128 (19) 8,277
--------------------------------------------------------------------------
Total assets 235 492 128 (19) 9,831
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Gross capital
expenditures 7 6 1 - 333
--------------------------------------------------------------------------
--------------------------------------------------------------------------
(1) The Terasen Gas companies were acquired on acquired on May 17,
(2) Includes Maritime Electric and FortisOntario
(3) Includes Belize Electricity, Fortis Turks and Caicos, and
Caribbean Utilities
Inter-segment transactions are in the normal course of operations and are
measured at the exchange amount, which is the amount of consideration
established and agreed to by the related parties. The significant inter-segment
transactions primarily related to the sale of energy from Fortis Generation to
Belize Electricity and from Fortis Generation to FortisOntario, electricity
sales from Newfoundland Power to Fortis Properties and finance charges on
inter-segment borrowings. The significant inter-segment transactions for the
three and six months ended June 30, 2008 and 2007 were as follows.
Inter-Segment Transactions
Quarter Ended Year-to-date
June 30 June 30
($ millions) 2008 2007 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Sales from Fortis
Generation to Belize
Electricity 4 3 7 8
Sales from Fortis
Generation to
FortisOntario 1 1 1 1
Sales from Newfoundland
Power to Fortis
Properties 1 1 2 2
Inter-segment finance
charges on borrowings
from:
Corporate to Regulated
Electric Utilities
- Canadian 1 - 1 1
Corporate to Regulated
Electric Utilities
- Caribbean 2 1 2 1
Corporate to Fortis
Properties 2 2 4 4
-------------------------------------------------------------------------
-------------------------------------------------------------------------
16. CAPITAL MANAGEMENT
The Corporation's principal businesses of regulated gas and electricity
distribution require ongoing access to capital in order to allow them to fund
maintenance and expansion of infrastructure. Wherever possible, Fortis raises
debt at the subsidiary level to ensure regulatory transparency, tax efficiency
and financing flexibility. To help ensure access to capital, the Corporation
targets a consolidated long-term capital structure containing approximately 40
per cent equity, including preference shares, 60 per cent debt and
investment-grade credit ratings.
Each of the Corporation's regulated utilities maintains its own capital
structure in line with the deemed capital structure reflected in the utility's
customer rates. Fortis generally finances a significant portion of acquisitions
with proceeds from common and preference share issuances.
The consolidated capital structure of Fortis is presented in the following table.
As at As at
June 30, December 31,
2008 2007
($ millions) (%) ($ millions) (%)
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Total debt and
capital lease
obligations
(net of cash) (1) 5,262 61.2 5,476 64.3
Preference
shares (2) 667 7.8 442 5.2
Common shareholders'
equity 2,668 31.0 2,601 30.5
-------------------------------------------------------------------------
Total 8,597 100.0 8,519 100.0
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) Includes long-term debt, including current portion, and short-term
borrowings, net of cash
(2) Includes preference shares classified as both long-term liabilities and
equity
Certain of the Corporation's long-term debt obligations have covenants
restricting the issuance of additional debt such that consolidated debt cannot
exceed 70 per cent of the Corporation's capital structure, as defined by the
long-term debt agreements. As at June 30, 2008, the Corporation and its
subsidiaries, except for Belize Electricity, were in compliance with their debt
covenants.
As a result of the PUC's Final Decision on Belize Electricity's 2008/2009 rate
application, Belize Electricity does not meet certain debt covenant financial
ratios resulting in approximately $16 million (BZ$30 million) of indebtedness
being in default as at June 30, 2008. In accordance with certain of these debt
covenants, Belize Electricity is also prohibited from incurring new indebtedness
or declaring dividends. The Company has informed the lenders of the situation
and has requested appropriate waivers. As at June 30, 2008, $10 million of the
above debt was reclassified from long-term to current on the balance sheet.
The Corporation's credit ratings and consolidated credit facilities are
discussed further under "Liquidity Risk" in Note 18.
17. FINANCIAL INSTRUMENTS
Fair Values
The Corporation has designated its financial instruments as follows:
As at As at
June 30, 2008 December 31, 2007
Carrying Estimated Carrying Estimated
($ millions) Value Fair Value Value Fair Value
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Held for trading
Cash and cash
equivalents (1) 59 59 58 58
Derivative financial
instruments
Derivative financial
instrument
assets (2)(3) 213 213 5 5
Derivative financial
instrument
liabilities (3)(4) - - 79 79
Loans and receivables
Trade and other
accounts
receivable (1)(2)(5) 523 523 630 630
Other receivables due
from customers (1)(5)(6) 7 7 7 7
Other financial
liabilities
Short-term
borrowings (1)(5) 279 279 475 475
Trade and other
accounts
payable (1)(4)(5) 685 685 714 714
Dividends
payable (1)(5) 42 42 43 43
Customer
deposits (1)(5)(7) 6 6 5 5
Long-term debt,
including current
portion (8)(9) 5,006 5,483 5,023 5,635
Preference shares,
classified as
debt (8)(10) 320 340 320 346
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(1) Due to the nature and/or short-term maturity of these financial
instruments, carrying value approximates fair value.
(2) Included in accounts receivable on the balance sheet
(3) Recorded at fair value
(4) Included in accounts payable and accrued charges on the balance sheet
(5) Carrying value approximates amortized cost.
(6) Included in deferred charges and other assets on the balance sheet
(7) Included in deferred credits on the balance sheet
(8) Carrying value is measured at amortized cost using the effective
interest rate method.
(9) Carrying value at June 30, 2008 is net of unamortized deferred
financing costs of $36 million (December 31, 2007 - $33 million).
(10) Preference shares classified as equity are excluded from the
requirements of the CICA Handbook Section 3855, Financial Instruments
- Recognition and Measurement; however, the estimated fair value of
the Corporation's $347 million preference shares classified as equity
was $326 million as at June 30, 2008 (December 31, 2007: carrying
value $122 million; fair value $107 million).
The carrying values of financial instruments included in current assets, current
liabilities, deferred charges and other assets, and deferred credits in the
consolidated balance sheets approximate their fair value, reflecting the
short-term maturity, normal trade credit terms and/or the nature of these
instruments. The fair value of long-term debt is calculated by using quoted
market prices when available, or by discounting the future cash flow of each
debt instrument at the estimated yield to maturity for the same or similar debt
issues at the balance sheet date. Since the Corporation does not intend to
settle the long-term debt prior to maturity, the fair value estimate does not
represent an actual liability and, therefore, does not include exchange or
settlement costs. The fair value of the Corporation's preference shares is
determined using quoted market prices.
The Corporation and its subsidiaries hedge exposures to fluctuations in interest
rates, foreign exchange rates and natural gas prices through the use of
derivative financial instruments. The Corporation does not hold or issue
derivative financial instruments for trading purposes. The following table
summarizes the valuation of the Corporation's derivative financial instruments.
As at As at
June 30, 2008 December, 31, 2007
Term to Number Carrying Estimated Carrying Estimated
maturity of Value Fair Value Value Fair Value
(Liability) (years) Contracts ($ ($ ($ ($
Asset millions) million) millions) millions)
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Interest rate
swaps 1 to 2 4 (1) (1) - -
Foreign
exchange
forward
contract 3 1 - - - -
Natural gas
derivatives:
Swaps and
options Up to 3 214 212 212 (79) (79)
Gas purchase
contract less
premiums than 1 53 1 1 5 5
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Two of the four interest rate swaps are held by Fortis Properties and are
designated as hedges of the cash flow risk related to floating-rate long-term
debt. The effective portion of changes in the value of the interest rate swaps
at Fortis Properties is recorded in other comprehensive income. The remaining
interest rate swaps are held by the Terasen Gas companies. The interest rate
swaps are designated as hedges of cash flow risk related to floating-rate debt
instruments.
The foreign exchange forward contract is held by TGVI and is designated as a
hedge of the cash flow risk related to approximately US$55 million required to
be paid under a contract for the construction of a liquefied natural gas ("LNG")
storage facility. The carrying value and estimated fair value of the forward
contract were immaterial as at June 30, 2008.
The natural gas derivatives are used to fix the effective purchase price of
natural gas, as the majority of the natural gas supply contracts have floating,
rather than fixed, prices. At the Terasen Gas companies, changes in the fair
value of the interest rate swaps, foreign exchange forward contracts and natural
gas derivatives are deferred as a regulatory asset or liability, subject to
regulatory approval, for recovery from, or refund to, customers in future rates.
The fair values of the natural gas derivatives were recorded in accounts
receivable as at June 30, 2008 (December 31, 2007 - in accounts payable and
accounts receivable).
The interest rate swaps are valued at the present value of future cash flows
based on published forward future interest rate curves. The foreign exchange
forward contract is valued at the present value of future cash flows based on
published forward future foreign exchange market rate curves. The fair values
of the natural gas derivatives reflect the estimated amounts, based on published
forward curves, that the Corporation would have to receive or pay if forced to
settle all outstanding contracts at the balance sheet date.
The fair value of the Corporation's financial instruments, including
derivatives, reflects a point-in-time estimate based on relevant market
information about the instruments. The estimates cannot be determined with
precision as they involve uncertainties and matters of judgment and, therefore,
may not be relevant in predicting the Corporation's future earnings or cash
flows.
The Corporation's earnings from and net investment in self-sustaining foreign
subsidiaries are exposed to fluctuations in the US dollar-to-Canadian dollar
exchange rate. The Corporation has effectively decreased the above exposure
through the use of US dollar borrowings. Foreign currency exchange rate
fluctuations associated with the translation of the Corporation's US dollar
borrowings designated as hedges of the Corporation's foreign net investments are
recorded in other comprehensive income. The Corporation may also periodically
enter into hedges of its foreign currency exposures by entering into forward
foreign currency contracts.
18. FINANCIAL RISK MANAGMENT
The Corporation is primarily exposed to credit risk, liquidity risk and market
risk as a result of holding financial instruments in the normal course of
business.
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Credit risk Risk that a third party to a financial instrument might
fail to meet its obligations under the terms of the
financial instrument.
--------------------------------------------------------------------------
Liquidity risk Risk that an entity will encounter difficulty in raising
funds to meet commitments associated with financial
instruments.
--------------------------------------------------------------------------
Market risk Risk that the fair value or future cash flows of a
financial instrument will fluctuate due to changes in
market prices. The Corporation is exposed to the following
market risks:
- Foreign exchange risk
- Interest rate risk
- Commodity price risk
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Credit Risk
For cash and cash equivalents, trade and other accounts receivable, and other
receivables due from customers, the Corporation's credit risk is limited to the
carrying value on the balance sheet. The Corporation generally has a large and
diversified customer base, which minimizes the concentration of credit risk.
The Corporation and its subsidiaries have various policies to minimize credit
risk and these include requiring customer deposits and credit checks for certain
customers and performing disconnections and/or using third-party collection
agencies for overdue accounts.
FortisAlberta has a concentration of credit risk as a result of its
distribution-service billings being to a relatively small group of retailers
and, as at June 30, 2008, its gross exposure was approximately $84 million,
representing the projected value of retailer billings over a 60-day period. The
Company has reduced its exposure to less than $3 million by obtaining from the
retailers either a cash deposit, bond, letter of credit, an investment-grade
credit rating from a major rating agency or by having the retailers obtain a
financial guarantee from an entity with an investment-grade credit rating.
The Terasen Gas companies are exposed to credit risk in the event of
non-performance by counterparties to derivative financial instruments, including
natural gas derivatives. The Terasen Gas companies are also exposed to
significant credit risk on physical off-system sales. To mitigate credit risk,
the Terasen Gas companies deal with high credit-quality institutions, in
accordance with established credit-approval practices. The counterparties with
which the Terasen Gas companies have significant transactions are A-rated
entities or better. The Company uses netting arrangements to reduce credit risk
and net settles payments with counterparties where net settlement provisions
exist.
The aging analysis of the Corporation's consolidated trade and other accounts
receivable, derivative financial instrument assets and other receivables due
from customers is as follows:
As at
($ millions) June 30, 2008
-----------------------------------------------------------
-----------------------------------------------------------
Not past due 647
Past due 0-30 days 66
Past due 31-60 days 18
Past due 61 days and over 26
-----------------------------------------------------------
757
Less: allowance for doubtful accounts (14)
-----------------------------------------------------------
743
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Liquidity Risk
The Corporation's financial position could be adversely affected if it or its
operating subsidiaries fail to arrange sufficient and cost-effective financing
to fund, among other things, capital expenditures and the repayment of maturing
debt. The ability to arrange sufficient and cost-effective financing is subject
to numerous factors, including the results of operations and financial position
of the Corporation and its subsidiaries, conditions in the capital and bank
credit markets, ratings assigned by rating agencies and general economic
conditions.
To mitigate this risk, the Corporation and its larger regulated utilities have
secured multi-year committed credit facilities to support short-term financing
of capital expenditures and seasonal working capital requirements. Committed
credit facilities at Fortis are available for interim financing of acquisitions
and for general corporate purposes.
As at June 30, 2008, the Corporation and its subsidiaries had consolidated
authorized lines of credit of $2.2 billion, of which $1.8 billion was unused.
The following summary outlines the credit facilities of the Corporation and its
subsidiaries.
Total as at Total as at
Corporate Regulated Fortis June 30, December 31,
($ millions) and Other Utilities Properties 2008 2007
------------------------------------------------------------------------
------------------------------------------------------------------------
Total credit
facilities 715 1,490 13 2,218 2,234
Credit facilities
utilized:
Short-term
borrowings - (279) - (279) (475)
Long-term debt
(Note 7) (1) - (54) - (54) (530)
Letters of credit
outstanding (1) (89) (1) (91) (159)
------------------------------------------------------------------------
Credit facilities
available 714 1,068 12 1,794 1,070
------------------------------------------------------------------------
------------------------------------------------------------------------
(1) As at June 30, 2008, credit -facility borrowings classified as long-
term debt included $27 million that was included in current
installments of long-term debt and capital lease obligations on the
balance sheet.
At June 30, 2008 and December 31, 2007, certain borrowings under the
Corporation's and subsidiaries' credit facilities have been classified as
long-term debt. These borrowings are under long-term committed credit facilities
and management's intention is to refinance these borrowings with long-term
permanent financing during future periods.
Letters of credit of $50 million previously outstanding at Terasen Inc., related
to its previously owned petroleum transportation business and secured by a
letter of credit from the former parent company, were cancelled during the
second quarter of 2008.
In April 2008, FortisBC renegotiated and amended its $150 million unsecured
committed revolving credit facility, extending the maturity date of the $50
million portion of the facility to May 2011 from May 2010 and extending the $100
million portion to May 2009 from May 2008. The Company has the option to
increase the credit facility to an aggregate of $200 million, subject to bank
approval.
In April 2008, Maritime Electric repaid all outstanding borrowings under its $25
million unsecured credit facility with partial proceeds from a $60 million bond
issue. The credit facility matured in May 2008 and was not renewed. As at June
30, 3008, Maritime Electric had a $45 million unsecured revolving credit
facility.
In July 2008, TGI renegotiated its $500 million unsecured committed revolving
credit facility extending the maturity date of the facility to August 2013 from
August 2012.
Furthermore, the Corporation and its subsidiaries target investment-grade credit
ratings to maintain capital market access at reasonable interest rates. As at
June 30, 2008, the Corporation's credit ratings were as follows:
Standard & Poors A- (long-term corporate and unsecured debt credit
rating)
DBRS BBB(high) (unsecured debt credit rating)
The credit ratings reflect the diversity of the operations of Fortis, the
stand-alone nature and financial separation of each of the regulated
subsidiaries of Fortis, management's commitment to maintaining low levels of
debt at the holding company level and the continued focus of Fortis on pursuing
acquisitions of stable regulated utilities.
The following is an analysis of the contractual maturities of the Corporation's
financial liabilities as at June 30, 2008.
Financial Liabilities
lesser or greater greater
egual than than than
($ millions) 1 year 1-3 years 4-5 years 5 years Total
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Short-term borrowings 279 - - - 279
Accounts payable and
accrued charges 685 - - - 685
Dividends payable 42 - - - 42
Customer deposits 2 2 1 1 6
Long-term debt, including
current portion (1) 335 314 123 4,271 5,043
Preference shares,
classifie as debt - - - 320 320
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1,343 316 124 4,592 6,375
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(1) Excluding deferred financing costs of $36 million included in the
carrying value as per Note 17
Market Risk
Foreign Exchange Risk
The Corporation's earnings from and net investment in self-sustaining foreign
subsidiaries are exposed to fluctuations in the US dollar-to-Canadian dollar
exchange rate. The Corporation has effectively decreased the above exposure
through the use of US dollar borrowings. The foreign exchange gain or loss on
the translation of US dollar denominated interest expense partially offsets the
foreign exchange gain or loss on the translation of US dollar denominated
earnings derived from foreign investments.
As at June 30, 2008, all of the Corporation's US$390 million of long-term debt
had been designated as a hedge of a portion of the Corporation's foreign net
investments. As at June 30, 2008, the Corporation had approximately US$72
million in foreign net investments remaining to be hedged.
As of January 1, 2008, an appreciation of 5 per cent of the US
dollar-to-Canadian dollar exchange rate would not have had a material impact on
earnings for the three and six months ended June 30, 2008 and would have
decreased other comprehensive income by $20 million for the six months ended
June 30, 2008. The impact on other comprehensive income for the three months
ended June 30, 2008 was immaterial. This sensitivity analysis is limited to the
impact of the translation of US dollar interest expense on earnings and the
impact of the translation of the US dollar borrowings on other comprehensive
income. The sensitivity analysis excludes the risk arising from the translation
of self-sustaining foreign operations to the Canadian dollar because this
exposure is limited to the net investment in these operations which is not a
financial instrument.
TGVI's US dollar payments under a contract for construction of an LNG storage
facility is exposed to fluctuations in the US dollar-to-Canadian dollar exchange
rate. TGVI has entered into a foreign exchange forward contract to hedge this
exposure. At June 30, 2008, a 50 basis point increase the US dollar-to-Canadian
dollar exchange rate, as it impacts the measurement of the fair value of foreign
exchange forward contract, in the absence of rate regulation and with all other
variables constant, would not have had a material impact on other comprehensive
income during the three and six months ended June 30, 2008. Furthermore, TGVI
expects to obtain regulatory approval to defer any increase or decrease in the
fair value of the foreign exchange forward contract for recovery from, or refund
to, customers in future rates. Therefore, any change in fair value would have
impacted regulatory assets or liabilities rather than other comprehensive
income.
Interest Rate Risk
The Corporation and its operating subsidiaries are exposed to interest rate risk
associated with short-term borrowings and floating-rate debt. The Corporation
and its operating subsidiaries may enter into interest rate swap agreements to
help reduce this risk and, during the first half of 2008, the Terasen Gas
companies and Fortis Properties were parties to interest rate swap agreements
that effectively fixed the interest rates on their variable-rate borrowings. As
of January 1, 2008, a 50 basis point increase in interest rates associated with
variable-rate debt, with all other variables remaining constant, would not have
had a material impact on earnings for the three and six months ended June 30,
2008. Furthermore, certain regulated subsidiaries have regulatory approval to
defer any increase or decrease in interest rate expense resulting from
fluctuations in interest rates associated with variable rate debt, for recovery
from, or refund to, customers in future rates.
As at June 30, 2008, a 50 basis point increase in interest rates as it impacts
the measurement of fair value of the interest rate swap agreements, in the
absence of rate regulation and with all other variables remaining constant,
would not have had a material impact on other comprehensive income during the
three and six months ended June 30, 2008. Furthermore, the Terasen Gas
companies have regulatory approval to defer any increase or decrease in the fair
value of the interest rate swap agreements for recovery from, or refund to,
customers in future rates. Therefore, any change in fair value would have
impacted regulatory assets or liabilities rather than other comprehensive
income.
In addition, certain of the committed credit facilities have fees that are
linked to the Corporation's or subsidiaries' credit ratings. As of January 1,
2008, a downward change in the credit ratings of the Corporation and its
currently rated subsidiaries by one level, with all other variables remaining
constant, would not have had a material impact on earnings for the three and six
months ended June 30, 2008.
Commodity Price Risk
The Terasen Gas companies are exposed to commodity price risk associated with
changes in the market price of natural gas. This risk is minimized by entering
into natural gas derivatives that effectively fix the price of natural gas
purchases. The natural gas derivatives are recorded on the balance sheet at
fair value and any change in the fair value is deferred as a regulatory asset or
liability, subject to regulatory approval, for recovery from, or refund to,
customers in future rates.
As of January 1, 2008, had the price of natural gas, with all other variables
remaining constant, increased by $1 per gigajoule, the fair value of the natural
gas derivatives would have increased and, in the absence of rate regulation,
other comprehensive income would have increased by $1 million and $67 million
for the three and six months ended June 30, 2008, respectively. However, the
Terasen Gas companies defer any changes in fair value of the natural gas
derivatives, subject to regulatory approval, for future recovery from, or refund
to, customers in future rates. Therefore, instead of increasing other
comprehensive income, the impact would have increased current regulatory
liabilities.
19. CONTINGENT LIABILITIES AND COMMITMENTS
Contingent liabilities
The Corporation and its subsidiaries are subject to various legal proceedings
and claims that arise in the ordinary course of business operations. The
Corporation's contingent liabilities are consistent with disclosures in the
Corporation's 2007 Annual Audited Consolidated Financial Statements.
Commitments
The nature and amount of the Corporation's commitments are comparable to those
disclosed in the Corporation's Annual Consolidated Financial Statements for the
year ended December 31, 2007, except for those described below for TGVI,
FortisOntario, Maritime Electric, Caribbean Utilities and Fortis Turks and
Caicos.
In April 2008, TGVI, after receiving regulatory approval, entered into a
contract with a third party for the engineering procurement and construction of
an LNG storage facility on Vancouver Island. The contract includes
approximately $55 million to be paid in US dollars. To mitigate the currency
fluctuations on the US dollar portion of the contract, the Company entered into
a three-year US dollar forward-purchase contact (Note 17).
FortisOntario has entered into a new 11.5 year take-or-pay contract between
Cornwall Electric and Hydro-Quebec Energy Marketing for the supply of
electricity and capacity. The contract, which expires on December 31, 2019,
replaces the previous two-year contract that expired on June 30, 2008. This
take-or-pay contract provides energy up to 100 MW on an as-needed basis and
provides a minimum 300,000 megawatt hours of energy per contract year beginning
July 1, 2008. The contract totals approximately $309 million.
Maritime Electric has two new take-or-pay contracts for the purchase of either
capacity or energy. The contracts total approximately $108 million through
November 30, 2032. The take-or-pay contract with New Brunswick Power includes,
among other things, replacement energy and capacity for the Point Lepreau
Nuclear Generating Station during its 18-month refurbishment outage. The other
take-or-pay contract is for transmission capacity allowing Maritime Electric to
reserve 30 MW of capacity on the new International Power Line into the United
States.
Caribbean Utilities has entered into a project agreement to purchase a 16-MW
diesel generating unit and related equipment from a supplier in Germany for
approximately US$24 million. The unit is expected to be commissioned in summer
2009. Approximately US$5 million has been incurred under the project as at June
30, 2008.
Caribbean Utilities has a primary fuel supply contract with a major supplier and
is committed to purchase 80 per cent of the Company's fuel requirements from
this supplier for the operation of Caribbean Utilities' diesel-fired generating
plant. The contract is for three years terminating in April 2010. The
remaining approximate quantities, in millions of imperial gallons, required to
be purchased annually during each of Caribbean Utilities' fiscal years ended
April 30 are: 2009 - 26 and 2010 - 28.
Fortis Turks and Caicos has a renewable contract with a major supplier for all
of its diesel fuel requirements associated with the generation of electricity.
The approximate fuel requirements under this contract are 12 million imperial
gallons per annum.
20. COMPARATIVE FIGURES
Certain comparative figures have been reclassified to comply with current period
classifications.
21. SUBSEQUENT EVENT
Subsequent to June 30, 2008, Terasen reached a settlement with Revenu Quebec and
Canada Revenue Agency related to amounts owing as a result of retroactive
amending Quebec tax legislation. The legislation was passed in 2006 for the
purpose of challenging certain inter-provincial Canadian tax structures. In
2006, Terasen had provided for amounts owing as a result of the retroactive
legislation. In August 2008, Terasen made a payment of approximately $16.7
million to settle the tax liability. As a result of the tax settlement, an
earnings' benefit of approximately $7.5 million is expected to be recorded
during the third quarter of 2008.
CORPORATE INFORMATION
Fortis Inc. is the largest investor-owned distribution utility in Canada. With
total assets of approximately $10.5 billion and annual revenues of more than
$2.7 billion, the Corporation serves almost 2,000,000 gas and electricity
customers. Its regulated holdings include a natural gas utility in British
Columbia and electric distribution utilities in five Canadian provinces and
three Caribbean countries. Fortis owns non-regulated generation assets across
Canada and in Belize and Upper New York State. It also owns hotels and
commercial real estate across Canada. Fortis Inc. shares are listed on the
Toronto Stock Exchange and trade under the symbol FTS.
Share Transfer Agent and Registrar:
Computershare Trust Company of Canada
9th Floor, 100 University Avenue
Toronto, ON M5J 2Y1
T: 514.982.7555 or 1.866.586.7638
F: 416.263.9394 or 1.888.453.0330
E: service@computershare.com
W: www.computershare.com
For the quarter ended June 30, 2008, Fortis Inc. will be filing the
Certification of Interim Filings (Form 52-109F2) on SEDAR. Additional
information, including the Fortis 2007 Annual Information Form, Management
Information Circular and Annual Report, are available on SEDAR at www.sedar.com
and on the Corporation's web site at www.fortisinc.com.
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