EX-99.1 2 a07-2962_1ex99d1.htm PRESS RELEASE DATED JANUARY 30, 2007

EXHIBIT 99.1

DRAFT
TransCanada Corporation

 

Media Inquiries:

Jennifer Varey/Shela Shapiro

 

(403) 920-7859

 

 

 

(800) 608-7859

Analyst Inquiries:

David Moneta/Myles Dougan

 

(403) 920-7911

 

NewsRelease

TransCanada Reports 2006 Net Income of $1.1 Billion
Board of Directors Increases Quarterly Dividend

CALGARY, Alberta —January 30, 2007 — (TSX: TRP) (NYSE: TRP)

Fourth Quarter and Year-End 2006 Financial Highlights

(All financial figures are unaudited and in Canadian dollars unless noted otherwise)

·                  Quarterly dividend of $0.34 per common share declared by the Board of Directors, an increase of six per cent

·                  Net income for fourth quarter 2006 of $269 million, or $0.55 per share

·                  Net income for the year ended December 31, 2006 of $1,079 million, or $2.21 per share

·                  Funds generated from operations for fourth quarter 2006 of $660 million; for the year ended December 31, 2006, $2,378 million

The Board of Directors of TransCanada Corporation (TransCanada or the company) today declared a quarterly dividend of $0.34 per common share for the quarter ending March 31, 2007, a six per cent increase over the $0.32 paid in each of the previous four quarters.  The dividend is payable on April 30, 2007 to shareholders of record at the close of business on March 30, 2007. This is the seventh consecutive annual increase in the common share dividend.

TransCanada today announced net income and net income from continuing operations (net earnings) for fourth quarter 2006 of $269 million or $0.55 per share compared to $350 million or $0.72 per share for fourth quarter 2005.

Excluding income tax refunds and related interest of $12 million in fourth quarter 2006, and an after-tax gain of $115 million in fourth quarter 2005 from the sale of the company’s interest in PT Paiton Energy Company (Paiton Energy), net earnings for fourth quarter 2006 were $257 million compared to $235 million in fourth quarter 2005, an increase of $22 million, or $0.05 per share.



Net income for the year ended December 31, 2006 was $1,079 million or $2.21 per share, including net income from discontinued operations of $28 million or $0.06 per share. Net income for the year ended December 31, 2005 was $1,209 million or $2.49 per share.

For the year ended December 31, 2006, net earnings were $1,051 million or $2.15 per share compared to $1,209 million or $2.49 per share for the year ended December 31, 2005.  In addition to the income tax refunds and related interest of $12 million recorded in fourth quarter 2006, net earnings for the year ended December 31, 2006 included an income tax benefit of approximately $50 million in the third quarter, an $18 million after-tax bankruptcy settlement receipt from a former shipper on the Gas Transmission Northwest System, a $33 million future income tax benefit as a result of reductions in Canadian federal and provincial corporate income tax rates, and a $13 million after-tax gain related to the sale of the company’s general partnership interest in Northern Border Partners, L.P.  In addition to the $115 million gain recorded in fourth quarter 2005 noted above, net earnings for the year ended December 31, 2005 included an after-tax gain of $193 million from the sale of TransCanada’s interest in TransCanada Power, L.P. (Power LP), an after-tax gain of $49 million on the sale of TC PipeLines, LP (PipeLines LP) common units, and $13 million related to 2004 as a result of a decision from the National Energy Board (NEB) in April 2005 on Phase II of the Canadian Mainline’s 2004 Tolls and Tariff Application. Excluding all of these items, net earnings for the year ended December 31, 2006 were $925 million, compared to $839 million in the same period in 2005, an increase of $86 million or $0.17 per share.

Funds generated from operations for fourth quarter 2006 were $660 million, an increase of $130 million compared to fourth quarter 2005.  Funds generated from operations for the year ended December 31, 2006 were $2,378 million, an increase of $427 million compared to 2005.

“In 2006, TransCanada continued to expand its portfolio of high quality pipeline and energy assets by advancing a number of significant growth initiatives and delivering solid returns to our shareholders,” said Hal Kvisle, TransCanada’s Chief Executive Officer.  “We continue to invest in our North American gas transmission and power businesses and to pursue new and complementary opportunities in natural gas storage, oil pipelines and liquefied natural gas.  Over the past seven years, we have invested more than $10 billion, with $2.0 billion invested last year alone.  In each of the next three years, we have already identified approximately $1.5 billion in capital investment, in addition to our pending acquisition of ANR.

“Our financial results for the year reflect our success in diligently and prudently executing our growth strategy.  In 2006, excluding gains and non-recurring items, TransCanada recorded significant increases in net earnings and funds generated from operations. Our strong 2006 financial performance has enabled our Board of Directors to increase the dividend on the company’s common shares for the seventh year in a row,” added Mr. Kvisle.

During fourth quarter 2006, TransCanada announced the acquisition of the American Natural Resources Company and the ANR Storage Company (together, ANR) and an additional interest in Great Lakes Gas Transmission Limited Partnership (Great Lakes) for US$3.4 billion including US$457 million of assumed debt.  TransCanada anticipates closing the acquisition in first quarter 2007.  ANR operates a 17,000 kilometre (km) natural gas pipeline system with a peak-day capacity of 6.8 billion cubic feet per day (Bcf/d).  ANR also owns and operates natural gas storage facilities with a total capacity of approximately 230 billion cubic feet (Bcf).  Great Lakes owns and operates a 3,400 km interstate natural gas pipeline system with a design capacity of 2.5 Bcf/d.

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“The ANR and Great Lakes acquisition represents a unique opportunity to acquire regulated pipeline and storage assets that are a strong fit with our existing North American footprint,” said Mr. Kvisle.  “They are high quality assets that will strengthen our position as a leader in the North American gas transmission business and deliver significant value to our shareholders.”

TransCanada expects to finance the ANR acquisition in a manner that is consistent with the company’s current balance sheet capitalization.  This is aligned with the company’s intention to maintain its strong financial position and TransCanada PipeLines Limited’s ‘A’ credit ratings.  TransCanada expects the transaction to be accretive to earnings and cash flow in the first full year of ownership.

Mr. Kvisle concluded, “The announcement of the ANR acquisition was a high point in a year of solid growth and continued advancement of our high quality portfolio of growth opportunities.  In 2006, we successfully completed several projects which are now contributing earnings and cash flow.  We brought 660 megawatts of power generation into commercial production through the completion of the Bécancour cogeneration plant and the first phase of the Cartier Wind project, and began transporting gas on the Tamazunchale pipeline in Mexico.  In addition, we completed commissioning of the Edson natural gas storage facility.

“We won the bid for the 683 megawatt Halton Hills Generating Station and, with our partner, Ontario Power Generation, negotiated an agreement with the Ontario Power Authority for the 550 megawatt Portlands Energy Centre.  These two plants will add significant incremental generating capacity to the Ontario power market and, along with our Bécancour plant, will increase demand for environmentally friendly natural gas.  We continued to advance major projects including the Keystone Oil Pipeline, the Bruce Power restart and refurbishment program, and the Cacouna and Broadwater liquefied natural gas terminals.  Over the longer term, we remain a key player in projects to bring northern natural gas to market.”

Notable developments in fourth quarter 2006 and the beginning of 2007 include:

Corporate:

·                  On January 23, 2007, TransCanada filed a preliminary short form shelf prospectus with securities regulators in Canada and the United States.  The preliminary short form shelf prospectus will allow for the offering of up to $3.0 billion of common shares, first preferred shares, second preferred shares and/or subscription receipts in Canada and the United States during the 25 month period that the short form prospectus remains valid.  The nature, size and timing of any financings would be dependent on TransCanada’s assessment of its requirements for funding and general market conditions.

·                  TransCanada’s issuer rating assigned by Moody’s Investors Service (Moody’s) is A3 with a stable outlook.  TransCanada PipeLines Limited’s (TCPL) senior unsecured debt is rated A, under review with developing implications, by Dominion Bond Rating Service Limited (DBRS); A2, with a stable outlook, by Moody’s; and A-, with a negative outlook, by Standard and Poor’s (S&P).  DBRS placed TCPL’s rating under review on December 22, 2006 as a result of the announcement of the proposed acquisition of ANR and Great Lakes.  Moody’s and S&P reaffirmed their ratings after the announcement.

·                  Today, TransCanada announced that it will issue common shares from treasury at a two per cent discount under TransCanada’s Dividend Reinvestment Plan (DRP), commencing with the dividend payable on April 30, 2007.  Previously, shares purchased through the DRP have been purchased by TransCanada on the open market and provided to DRP participants at cost.  The company reserves the right to alter the discount or return to purchasing shares on the open market at any time.

3



Pipelines:

·                  As noted above, on December 22, 2006 TransCanada announced plans to acquire ANR and an additional 3.55 per cent interest in Great Lakes.  In a separate transaction, PipeLines LP proposes to acquire the remaining 46.45 per cent interest in Great Lakes for US$962 million, including US$212 million of assumed debt.  TransCanada is the general partner and a common unitholder (13.4 per cent interest) of PipeLines LP.  TransCanada will become the operator of Great Lakes.  With the proposed acquisition of ANR, TransCanada’s wholly owned natural gas pipeline network will extend more than 59,000 km and offer customers unparalleled connections from traditional and emerging supply basins to growing North American markets.  This acquisition is also expected to increase TransCanada’s natural gas storage capacity to approximately 360 Bcf, making it one of North America’s largest natural gas storage operators. TransCanada anticipates closing the acquisition in the first quarter of 2007.

·                  TransCanada today announced the start of a binding Open Season for an expansion and extension of the proposed Keystone Oil Pipeline.  Through the Open Season, TransCanada seeks to obtain binding commitments to support the expansion of the proposed Keystone Pipeline from a nominal capacity of approximately 435,000 barrels per day to 590,000 barrels per day and the construction of a 468 km extension of the United States portion of the pipeline from the Nebraska/Kansas border to the refining and terminal hub near Cushing, Oklahoma.  The US$700 million expansion and extension project is targeted to be in service in fourth quarter 2010.  In December 2006, TransCanada filed an application with the NEB for a certificate of public convenience and necessity to construct and operate the Canadian portion of the Keystone Pipeline.  A decision on this application is anticipated from the NEB by the end of 2007. Oral hearings on TransCanada and Keystone’s June 2006 application to the NEB relating to the conversion of a section of the Canadian Mainline from natural gas to oil transmission concluded in November 2006.  The NEB is expected to issue a decision on the transfer application in the first quarter 2007.

·                  In December 2006, PipeLines LP closed its acquisition of an additional 50 per cent interest in the Tuscarora Gas Transmission Company (Tuscarora) for approximately US$100 million. PipeLines LP has also indirectly assumed US$37 million of Tuscarora debt.  PipeLines LP now owns or controls 99 per cent of Tuscarora.  TransCanada, the parent company of TC PipeLines GP, Inc. and the sole general partner of PipeLines LP, indirectly holds the remaining one per cent ownership interest. TransCanada has provided gas control services for the Tuscarora pipeline system since late 2002 and will become the operator of Tuscarora.

·                  TransCanada’s Tamazunchale pipeline in east-central Mexico began commercial operations on December 1, 2006.  The 130 km pipeline has an initial capacity of 170 million cubic feet per day (mmcf/d) and transports natural gas from the PEMEX gas pipeline system near Naranjos, Veracruz, to an electricity generation station near Tamazunchale, San Luis Potosi. Under the current contract with the Comisión Federal de Electricidad, beginning in 2009, the capacity of the Tamazunchale pipeline will be expanded to approximately 430 mmcf/d to meet the needs of two additional proposed power plants near Tamazunchale.

Energy:

·                  The first phase of the Cartier Wind project, the 109.5 megawatt (MW) Baie des Sables wind farm, was placed into service in late November 2006.  Construction continues on the 100.5 MW Anse à Valleau wind farm, the second of the six wind farms that comprise the Cartier Wind project in the Gaspé region of Québec.  It is expected to deliver energy to the Hydro-Québec grid by December 2007.  TransCanada has a 62 per cent interest in the Cartier Wind project which was awarded six projects by Hydro-Québec Distribution in October 2004 representing a total of 739.5 MW.

·                  In November 2006, TransCanada was awarded a 20-year Clean Energy Supply contract by the Ontario Power Authority (OPA) to build, own and operate a 683 MW natural gas-fired power plant near the Town of Halton Hills, Ontario. TransCanada expects to invest approximately $670 million in the Halton Hills Generating Station which is anticipated to be in service in the second quarter of 2010.

·                  Commissioning of the Edson natural gas storage facility in Alberta was completed at the end of fourth quarter 2006 and was placed into service December 31, 2006.  The Edson facility is expected to have a working natural gas capacity of approximately 60 petajoules and connects to the Alberta system.

Additional developments are discussed in this News Release under the title “Other Recent Developments”.

4



Fourth Quarter and Year End 2006 Financial Highlights

Operating Results

 

 

 

 

 

(millions of dollars)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

2,091

 

771

 

7,520

 

6,124

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

 

 

 

 

 

 

 

 

Continuing operations

 

269

 

350

 

1,051

 

1,209

 

Discontinued operations

 

—

 

—

 

28

 

—

 

 

 

269

 

350

 

1,079

 

1209

 

Cash Flows

 

 

 

 

 

 

 

 

 

Funds generated from operations (1)

 

660

 

530

 

2,378

 

1,951

 

(Increase)/decrease in working capital

 

(167

)

124

 

(303

)

(49

)

Net cash provided by operations

 

493

 

654

 

2,075

 

1,902

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

570

 

345

 

1,572

 

754

 

Acquisitions, net of cash acquired

 

112

 

685

 

470

 

1,317

 

 

 

 

Three months ended December 31

 

Year ended December 31

 

Common Share Statistics

 

2006

 

2005

 

2006

 

2005

 

 

 

 

 

 

 

 

 

 

 

Net Income Per Share - Basic

 

 

 

 

 

 

 

 

 

Continuing operations

 

$

0.55

 

$

0.72

 

$

2.15

 

$

2.49

 

Discontinued operations

 

—

 

—

 

0.06

 

—

 

 

 

$

0.55

 

$

0.72

 

$

2.21

 

$

2.49

 

 

 

 

 

 

 

 

 

 

 

Dividends Declared Per Share

 

$

0.32

 

$

0.305

 

$

1.28

 

$

1.22

 

 

 

 

 

 

 

 

 

 

 

Common Shares Outstanding (millions)

 

 

 

 

 

 

 

 

 

Average for the period - Basic

 

488.6

 

487.1

 

488.0

 

486.2

 

End of period

 

489.0

 

487.2

 

489.0

 

487.2

 

(1)             Funds generated from operations is discussed further in the section”Non-GAAP Measures in this news release.

8



Forward-Looking Information

Certain information in this news release includes forward-looking statements.  All forward-looking statements are based on TransCanada’s beliefs and assumptions based on information available at the time such statements were made.  Factors which could cause actual results or events to differ materially from current expectations include, among other things, the ability of TransCanada to successfully implement its strategic initiatives and whether such strategic initiatives will yield the expected benefits, the availability and price of energy commodities, regulatory decisions, changes in environmental and other laws and regulations, competitive factors in the pipeline and energy industry sectors, construction and completion of capital projects, access to capital markets, currency exchange rates, technological developments and the current economic condition in North America.  By its nature, such forward-looking information is subject to various risks and uncertainties, which could cause TransCanada’s actual results and experience to differ materially from the anticipated results or other expectations expressed.  Readers are cautioned not to place undue reliance on this forward-looking information, which is given as of the date of this news release or as otherwise stated.  TransCanada undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, except as required by law.

Non-GAAP Measures

The company uses the measures “funds generated from operations” and “operating income” in this news release. These measures do not have any standardized meaning in generally accepted accounting principles (GAAP) and are therefore considered to be non-GAAP measures. These measures may not be comparable to similar measures presented by other entities. These measures have been used to provide readers with additional information on the company’s liquidity and its ability to generate funds to finance its operations.

Funds generated from operations is comprised of net cash provided by operations before changes in operating working capital.  A reconciliation of funds generated from operations to net cash provided by operations is presented in the “Fourth Quarter and Year End 2006 Financial Highlights” table in this news release. Operating income is used in the Energy segment and is comprised of revenues plus income from equity investments less operating expenses as shown on the consolidated income statement.  Refer to the Energy section in this news release for a reconciliation of operating income to net earnings.

Results of Operations

Effective June 1, 2006, TransCanada revised the composition and names of its reportable business segments to Pipelines and Energy.  The financial reporting of these segments was aligned to reflect the internal organizational structure of the company.  Pipelines is principally comprised of the company’s pipelines in Canada, the United States and Mexico.  Energy includes the company’s power operations, natural gas storage business and LNG projects in Canada and the United States. The segmented information in this news release has been retroactively restated to reflect the changes in reportable segments. These changes had no impact on consolidated net income.

9



Consolidated

Segment Results-at-a-Glance
(millions of dollars except per share amounts)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Pipelines

 

 

 

 

 

 

 

 

 

Excluding gains

 

126

 

155

 

547

 

630

 

Gain on sale of Northern Border Partners, L.P. interest

 

—

 

—

 

13

 

—

 

Gain on sale of PipeLines LP units

 

—

 

—

 

—

 

49

 

 

 

126

 

155

 

560

 

679

 

Energy

 

 

 

 

 

 

 

 

 

Excluding gains

 

132

 

87

 

452

 

258

 

Gain on sale of Paiton Energy

 

—

 

115

 

—

 

115

 

Gains related to Power LP

 

—

 

—

 

—

 

193

 

 

 

132

 

202

 

452

 

566

 

Corporate

 

11

 

(7

)

39

 

(36

)

Net Income

 

 

 

 

 

 

 

 

 

Continuing operations (1)

 

269

 

350

 

1,051

 

1,209

 

Discontinued operations

 

—

 

—

 

28

 

—

 

 

 

269

 

350

 

1,079

 

1,209

 

Net Income Per Share

 

 

 

 

 

 

 

 

 

Continuing operations (2)

 

$

0.55

 

$

0.72

 

$

2.15

 

$

2.49

 

Discontinued operations

 

—

 

—

 

0.06

 

—

 

Basic

 

$

0.55

 

$

0.72

 

$

2.21

 

$

2.49

 

Diluted

 

$

0.54

 

$

0.71

 

$

2.20

 

$

2.47

 

(1)Net Income from Continuing Operations is comprised of:

 

 

 

 

 

 

 

 

 

Excluding gains

 

269

 

235

 

1,038

 

852

 

Gains related to Northern Border Partners, L.P. interest, PipeLines LP units, Power LP and Paiton Energy

 

—

 

115

 

13

 

357

 

 

 

269

 

350

 

1,051

 

1,209

 

(2)Net Income Per Share from Continuing

 

 

 

 

 

 

 

 

 

Operations is comprised of:

 

 

 

 

 

 

 

 

 

Excluding gains

 

$

0.55

 

$

0.48

 

$

2.12

 

$

1.75

 

Gains related to Northern Border Partners, L.P. interest, PipeLines LP units, Power LP and Paiton Energy

 

—

 

0.24

 

0.03

 

0.74

 

 

 

$

0.55

 

$

0.72

 

$

2.15

 

$

2.49

 

 

TransCanada’s net income and net earnings for fourth quarter 2006 were $269 million or $0.55 per share compared to $350 million or $0.72 per share for fourth quarter 2005.  The fourth quarter 2006 net earnings were lower than 2005 by $81 million or $0.17 per share, primarily due to an after-tax gain of $115 million or $0.24 per share from the sale of the company’s interest in Paiton Energy in fourth quarter 2005.  Excluding this gain, in fourth quarter 2006 the company reported an increase of $34 million in net income and net earnings, reflecting an increase in Energy’s net earnings, a decrease in Corporate’s net expenses, partially offset by a decrease in Pipelines’ net earnings, compared to 2005.

10



Pipelines’ net earnings for fourth quarter 2006 decreased $29 million primarily due to lower net earnings from the Canadian Mainline and the Alberta System as a result of lower rates of return on common equity (ROE) and lower average investment bases. Net earnings from the Gas Transmission Northwest System and the North Baja System (GTN) for fourth quarter 2006 decreased due to increased operating costs and lower transportation revenues. Net earnings for TransCanada’s Other Pipelines decreased primarily due to higher project development and support costs and the impact of a weaker U.S. dollar.

Excluding the gain related to the sale of Paiton Energy in fourth quarter 2005, Energy’s net earnings for fourth quarter 2006 increased $45 million compared to fourth quarter 2005 primarily due to higher operating income from Western Power Operations, Bruce Power and Natural Gas Storage, partially offset by lower operating income from Eastern Power Operations.

Corporate’s net earnings increased $18 million to $11 million in fourth quarter 2006 primarily due to income tax refunds and related interest of approximately $12 million and other positive income tax adjustments.

TransCanada’s net income for the year ended December 31, 2006 was $1,079 million or $2.21 per share, which included net income from discontinued operations of $28 million or $0.06 per share reflecting bankruptcy settlements with Mirant Corporation and certain of its subsidiaries (Mirant) received in first quarter 2006 related to TransCanada’s Gas Marketing business divested in 2001.  Net income for the year ended December 31, 2005 was $1,209 million or $2.49 per share.

TransCanada’s net earnings for the year ended December 31, 2006 were $1,051 million or $2.15 per share compared to $1,209 million or $2.49 per share for the same period in 2005.  The decrease of $158 million or $0.34 per share was primarily due to the $357 million of gains recognized on the sales in 2005 of PipeLines LP units, the company’s interest in Power LP and Paiton Energy.

Excluding the $49 million after-tax gain on the sale of PipeLines LP units in 2005 and the $13 million after-tax gain on the sale of TransCanada’s general partner interest in Northern Border Partners, L.P. in 2006, Pipelines’ net earnings for the year ended December 31, 2006 decreased $83 million compared to the same period in 2005.  This decrease was primarily due to lower net earnings from the Canadian Mainline and the Alberta System as a result of a lower ROE and lower average investment bases in 2006, compared to 2005.  In addition, the 2005 net earnings included a positive adjustment of $13 million related to 2004, resulting from the April 2005 NEB decision on the Canadian Mainline’s 2004 Tolls and Tariff Application (Phase II).  As well, TransCanada’s Other Pipelines and GTN experienced lower net earnings in 2006.  These decreases were partially offset by an $18 million ($29 million pre-tax) GTN bankruptcy settlement from Mirant, a former shipper, recorded in 2006.

Excluding the $193 million and $115 million after-tax gains in 2005 related to the sales of the Power LP interest and Paiton Energy, respectively, Energy’s net earnings for the year ended December 31, 2006 increased $194 million compared to the same period in 2005. This increase was primarily due to higher operating income from each of its existing businesses as well as a $23 million favourable impact on future income taxes arising from reductions in Canadian federal and provincial income tax rates enacted in second quarter 2006.  These increases were partially offset by the loss of operating income associated with the sale in third quarter 2005 of the Power LP investment and the negative impact of a weaker U.S. dollar.

The increase of $75 million in Corporate’s net earnings for the year ended December 31, 2006, compared to the same period in 2005, was primarily due to approximately $12 million in income tax refunds and related interest in fourth quarter 2006, a $50 million income tax benefit in third quarter 2006, as well as a $10 million favourable impact on future income taxes in second quarter 2006 arising from reductions in Canadian federal and provincial income tax rates.  In addition, net earnings in 2006 were positively impacted by the effect of a weaker U.S. dollar.

Results from each business segment for the three months and year ended December 31, 2006 are discussed further in the “Pipelines”, “Energy” and “Corporate” sections of this news release.

Funds generated from operations of $660 million and $2,378 million for the three months and year ended December 31, 2006 increased $130 million and $427 million, respectively, when compared to the same periods in 2005.

11



Pipelines

The Pipelines business generated net earnings of $126 million and $560 million for the three months and year ended December 31, 2006, respectively, compared to $155 million and $679 million for the same periods in 2005.

Pipelines Results-at-a-Glance
(millions of dollars)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Wholly Owned Pipelines

 

 

 

 

 

 

 

 

 

Canadian Mainline

 

60

 

67

 

239

 

283

 

Alberta System

 

34

 

38

 

136

 

150

 

GTN

 

7

 

18

 

64

 

71

 

Foothills System

 

5

 

5

 

21

 

21

 

BC System

 

1

 

1

 

6

 

6

 

 

 

107

 

129

 

466

 

531

 

Other Pipelines

 

 

 

 

 

 

 

 

 

Great Lakes

 

11

 

10

 

44

 

46

 

Iroquois

 

4

 

3

 

15

 

17

 

Portland

 

3

 

4

 

13

 

11

 

PipeLines LP

 

1

 

2

 

4

 

9

 

Ventures LP

 

3

 

3

 

12

 

12

 

TQM

 

2

 

2

 

7

 

7

 

TransGas

 

3

 

3

 

11

 

11

 

Gas Pacifico/INNERGY

 

3

 

4

 

8

 

6

 

Tamazunchale

 

2

 

—

 

2

 

—

 

Northern Development

 

(2

)

(1

)

(5

)

(4

)

General, administrative, support costs and other

 

(11

)

(4

)

(30

)

(16

)

 

 

19

 

26

 

81

 

99

 

Gain on sale of Northern Border Partners, L.P. interest

 

—

 

—

 

13

 

—

 

Gain on sale of PipeLines LP units

 

—

 

—

 

—

 

49

 

 

 

19

 

26

 

94

 

148

 

Net Earnings

 

126

 

155

 

560

 

679

 

 

12



Wholly Owned Pipelines

The Canadian Mainline’s fourth quarter 2006 net earnings decreased $7 million compared to fourth quarter 2005 primarily due to a lower ROE, as determined by the NEB, of 8.88 per cent in 2006 compared to 9.46 per cent in 2005 and a lower average investment base. Net earnings for the year ended December 31, 2006 decreased $44 million compared to 2005. This decrease was primarily due to the combination of a lower ROE and lower average investment base in 2006 compared to 2005.  In addition, 2005 net earnings included a positive adjustment of $13 million related to 2004, as a result of the NEB’s decision in April 2005 on the Canadian Mainline’s 2004 Tolls and Tariff Application (Phase II).  This NEB decision included an increase in the deemed common equity ratio from 33 per cent to 36 per cent for 2004 which was also effective for 2005 under the 2005 tolls settlement with shippers.

The Alberta System’s net earnings of $34 million in fourth quarter 2006 decreased $4 million compared to $38 million in the same quarter of 2005. Net earnings for the year ended December 31, 2006 decreased $14 million compared to the same period in 2005. These decreases were primarily due to a lower investment base in 2006 as well as a lower ROE in 2006. Net earnings in 2006 reflected an Alberta Energy and Utilities Board (EUB) allowed ROE of 8.93 per cent compared to 9.50 per cent in 2005, both on deemed common equity of 35 per cent.

GTN’s net earnings for the three months ended December 31, 2006 were $7 million, an $11 million decrease from the same period in 2005. This decrease was primarily due to increased operating costs, lower transportation revenues and a provision with respect to non-payment of contract transportation revenue from a subsidiary of Calpine Corporation (Calpine). Net earnings for the year ended December 31, 2006 were $64 million, a $7 million decrease from the same period in 2005. This decrease was primarily due to lower transportation revenues, nine months of Calpine provision, higher operating costs in 2006 and the negative impact of a weaker U.S. dollar. These decreases were partially offset by an $18 million bankruptcy settlement ($29 million pre-tax) in first quarter 2006 with Mirant, a former shipper, and lower long-term debt interest costs.

Operating Statistics

Year ended December 31

 

Canadian
Mainline (1)

 

Alberta System (2)

 

Gas Transmission
Northwest System(3)

 

Foothills System

 

BC System

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

2006

 

2005

 

2006

 

2005

 

2006

 

2005

 

Average investment base (millions of dollars)

 

7,459

 

7,807

 

4,287

 

4,446

 

n/a

 

n/a

 

645

 

680

 

205

 

216

 

Delivery volumes (Bcf)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total

 

2,955

 

2,997

 

4,051

 

3,999

 

790

 

777

 

1,051

 

1,051

 

256

 

321

 

Average per day

 

8.1

 

8.2

 

11.1

 

11.0

 

2.2

 

2.1

 

2.9

 

2.9

 

0.7

 

0.9

 

(1)             Canadian Mainline deliveries originating at the Alberta border and in Saskatchewan in 2006 were 2,224 billion cubic feet (Bcf) (2005 - 2,215 Bcf); average per day was 6.1 Bcf (2005 - 6.1 Bcf).

(2)             Field receipt volumes for the Alberta System in 2006 were 4,160 Bcf (2005 - 4,034 Bcf); average per day was 11.4 Bcf (2005 - 11.1 Bcf).

(3)             The Gas Transmission Northwest System operates under a fixed rate model approved by the United States Federal Energy Regulatory Commission (FERC) and, as a result, the system’s current results are not dependent on average investment base.

13



Other Pipelines

TransCanada’s proportionate share of net earnings from Other Pipelines was $19 million for the three months ended December 31, 2006 compared to $26 million for the same period in 2005.  Net earnings from Tamazunchale, which commenced commercial operations in December 2006, were more than offset by the impact of higher project development and support costs associated with growing the Pipelines business.

Net earnings for the year ended December 31, 2006 were $94 million compared to $148 million for the corresponding period in 2005.  Excluding the $13 million after-tax gain on the sale of the Northern Border Partners, L.P. interest recorded in 2006, and the $49 million after-tax gain on the sale of PipeLines LP units in 2005, net earnings for 2006 were $18 million lower compared to 2005.  This decrease is primarily due to higher project development and support costs associated with growing the Pipelines business, reduced ownership in PipeLines LP and a weaker U.S. dollar.

As at December 31, 2006, TransCanada had advanced $118 million to the Aboriginal Pipeline Group with respect to the Mackenzie Gas Pipeline Project and had capitalized $39 million related to Keystone.

Energy

Energy Results-at-a-Glance

(millions of dollars)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Bruce Power

 

59

 

53

 

235

 

195

 

Western Power Operations

 

109

 

33

 

297

 

123

 

Eastern Power Operations

 

55

 

68

 

187

 

137

 

Natural Gas Storage

 

30

 

17

 

93

 

32

 

Power LP Investment

 

—

 

—

 

—

 

29

 

General, administrative and support costs

 

(44

)

(36

)

(144

)

(129

)

Operating income

 

209

 

135

 

668

 

387

 

Financial charges

 

(6

)

(4

)

(23

)

(11

)

Interest income and other

 

—

 

—

 

5

 

5

 

Income taxes

 

(71

)

(44

)

(198

)

(123

)

 

 

132

 

87

 

452

 

258

 

Gain on sale of Paiton Energy

 

—

 

115

 

—

 

115

 

Gains related to Power LP

 

—

 

—

 

—

 

193

 

Net Earnings

 

132

 

202

 

452

 

566

 

 

Energy’s net earnings were $132 million in fourth quarter 2006, compared to $202 million in fourth quarter 2005.  In fourth quarter 2005, TransCanada recognized a gain of $115 million on the sale of Paiton Energy.

Excluding the gain of $115 million in 2005, Energy’s net earnings of $132 million in fourth quarter 2006 increased $45 million compared to $87 million in fourth quarter 2005 due to higher operating income from Western Power Operations, Natural Gas Storage and Bruce Power.  Partially offsetting these increases were lower operating income from Eastern Power Operations and higher general, administrative and support costs.

15



Bruce Power’s contribution to operating income increased $6 million in fourth quarter 2006 compared to fourth quarter 2005, primarily due to an increased ownership interest in the Bruce A facilities, the positive impact of higher generation volumes, partially offset by lower overall realized prices and higher operating expenses.

Western Power Operations’ operating income was $76 million higher in fourth quarter 2006, compared to fourth quarter 2005, primarily due to incremental earnings from the December 31, 2005 acquisition of the 756 MW Sheerness power purchase arrangement (PPA) and increased margins from a combination of higher overall realized power prices and higher market heat rates on sales of uncontracted power volumes.

Eastern Power Operations’ operating income was $13 million lower in fourth quarter 2006, compared to fourth quarter 2005, primarily due to record hurricane activity in the Gulf of Mexico which caused a significant increase in certain commodity prices and increased hydro generation volumes. As a result, higher profits were earned in 2005 from increased generation volumes as a result of unusually high water flows through the TC Hydro facilities, increased margins on the natural gas purchased and resold under the Ocean State Power (OSP) gas supply contracts and higher prices realized on power sold into the spot market.  The quarter over quarter decrease was partially offset by incremental income earned in 2006 from the startup of the 550 MW Bécancour cogeneration plant in September 2006 and the first of six wind farms at the Cartier Wind project in November 2006.

Natural Gas Storage operating income increased $13 million in fourth quarter 2006, compared to fourth quarter 2005, primarily due to higher contributions from CrossAlta as a result of increased storage capacity and higher natural gas storage spreads.

Excluding the 2005 gains of $115 million on the sale of Paiton Energy and $193 million related to the sale of the Power LP interest, Energy’s net earnings for the year ended December 31, 2006 of $452 million increased $194 million compared to $258 million for the same period in 2005.  The increase was due to higher contributions from each of its existing businesses and a $23 million decrease in future income taxes resulting from reductions in Canadian federal and provincial corporate income tax rates enacted in second quarter 2006.  Partially offsetting these increases was the loss of operating income associated with the sale of the Power LP interest in third quarter 2005 and reduced U.S. earnings due to a weaker U.S. dollar.

Bruce Power

Effective October 31, 2005, TransCanada increased its interest in the Bruce A units through the formation of the Bruce A partnership.  Bruce A subleases its facilities from Bruce B.  TransCanada commenced proportionately consolidating its investments in Bruce A and Bruce B effective October 31, 2005.  At December 31, 2006, TransCanada had a 48.7 per cent interest in Bruce A and a 31.6 per cent interest in Bruce B. The Bruce Power financial results on the following page reflect the operations of the full six-unit facility for both periods.

16



 

Bruce Power Results-at-a-Glance(1)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Bruce Power (100 per cent basis)

 

 

 

 

 

 

 

 

 

(millions of dollars)

 

 

 

 

 

 

 

 

 

Revenues

 

 

 

 

 

 

 

 

 

Power

 

465

 

476

 

1,861

 

1,907

 

Other (2)

 

28

 

13

 

71

 

35

 

 

 

493

 

489

 

1,932

 

1,942

 

Operating expenses

 

 

 

 

 

 

 

 

 

Operations and maintenance

 

(256

)

(231

)

(912

)

(871

)

Fuel

 

(28

)

(19

)

(96

)

(77

)

Supplemental rent

 

(43

)

(41

)

(170

)

(164

)

Depreciation and amortization

 

(35

)

(53

)

(134

)

(198

)

 

 

(362

)

(344

)

(1,312

)

(1,310

)

Revenues, net of operating expenses

 

131

 

145

 

620

 

632

 

Financial charges under equity accounting

 

—

 

(6

)

—

 

(58

)

 

 

131

 

139

 

620

 

574

 

TransCanada’s proportionate share

 

58

 

51

 

228

 

188

 

Adjustments

 

1

 

2

 

7

 

7

 

TransCanada’s operating income from Bruce Power(3)

 

59

 

53

 

235

 

195

 

 

 

 

 

 

 

 

 

 

 

Bruce Power - Other Information

 

 

 

 

 

 

 

 

 

Plant availability

 

 

 

 

 

 

 

 

 

Bruce A

 

97

%

 

 

81

%

 

 

Bruce B

 

85

%

 

 

91

%

 

 

Combined Bruce Power

 

89

%

79

%

88

%

80

%

Sales volumes (GWh) (4)

 

 

 

 

 

 

 

 

 

Bruce A - 100 per cent

 

3,210

 

 

 

10,650

 

 

 

Bruce B - 100 per cent

 

6,030

 

 

 

25,820

 

 

 

Combined Bruce Power - 100 per cent

 

9,240

 

8,300

 

36,470

 

32,900

 

TransCanada’ s proportionate share

 

3,469

 

2,946

 

13,317

 

10,732

 

Results per MWh (5)

 

 

 

 

 

 

 

 

 

Bruce A revenues

 

$

59

 

 

 

$

58

 

 

 

Bruce B revenues

 

$

46

 

 

 

$

48

 

 

 

Combined Bruce Power revenues

 

$

50

 

$

57

 

$

51

 

$

58

 

Combined Bruce Power fuel

 

$

3

 

$

2

 

$

3

 

$

2

 

Combined Bruce Power operating expenses(6)

 

$

38

 

$

41

 

$

35

 

$

40

 

Percentage of output sold to spot market

 

30

%

35

%

35

%

49

%

(1)             All information in the table includes adjustments to eliminate the effects of inter-partnership transactions between Bruce A and Bruce B.

(2)             Includes fuel cost recoveries for Bruce A of $11 million and $30 million, respectively, for the three and 12 months ended December 31, 2006.

(3)             TransCanada’s consolidated equity income includes $26 million and $168 million which represents TransCanada’s 31.6 per cent share of Bruce Power’s earnings for the one and ten months ended October 31, 2005, respectively.

(4)             Gigawatt hours.

(5)             Megawatt hours.

(6)             Net of fuel cost recoveries.

17



TransCanada’s operating income of $59 million from its combined investment in Bruce Power increased $6 million in fourth quarter 2006, compared to fourth quarter 2005, primarily due to an increased ownership interest in the Bruce A facilities and the positive impact of higher generation volumes, partially offset by lower overall realized prices and higher operating costs.

TransCanada’s share of Bruce Power’s generation for fourth quarter 2006 increased 523 GWh to 3,469 GWh, compared to fourth quarter 2005 generation of 2,946 GWh, as a result of an increased ownership in the Bruce A facilities and fewer planned and unplanned maintenance outage days in fourth quarter 2006.  Bruce Power prices achieved during fourth quarter 2006 (excluding other revenues) were $50 per MWh, compared to $57 per MWh in fourth quarter 2005.  Bruce Power’s operating expenses (net of fuel cost recoveries) in fourth quarter 2006 decreased to $38 per MWh from $41 per MWh in fourth quarter 2005 primarily due to increased output in fourth quarter 2006.

Approximately 43 reactor days of planned maintenance outages as well as approximately 12 reactor days of unplanned outages occurred on the six operating units in fourth quarter 2006.  In fourth quarter 2005, Bruce Power experienced 66 reactor days of planned maintenance outages and 35 reactor days of unplanned outages.  The Bruce Power units ran at a combined average availability of 89 per cent in fourth quarter 2006, compared to a 79 per cent average availability during fourth quarter 2005.

TransCanada’s operating income from its combined investment in Bruce Power for the year ended December 31, 2006 was $235 million compared to $195 million for the same period in 2005.  The increase of $40 million was primarily due to higher sales volumes resulting from increased plant availability and an increased ownership interest in the Bruce A facilities, partially offset by lower overall realized prices.

Combined Bruce Power prices achieved for the year ended December 31, 2006 (excluding other revenues) were $51 per MWh compared to $58 per MWh for 2005.  Bruce Power’s combined operating expenses (net of fuel cost recoveries) decreased to $35 per MWh for the year ended December 31, 2006 from $40 per MWh in 2005 primarily due to increased output in 2006.  The Bruce units ran at a combined average availability of 88 per cent in the year ended December 31, 2006 compared to 80 per cent in 2005.

The overall plant availability percentage in 2007 is expected to be in the low 90s for the four Bruce B units and in the mid 70s for the two operating Bruce A units.  Two planned outages are scheduled for Bruce A Unit 3 with the first outage expected to last one month in second quarter and a second outage expected to last approximately two months beginning in late third quarter 2007. A one month outage of Bruce A Unit 4 is expected to commence in first quarter 2007. The only planned maintenance outage for 2007 for Bruce B is an approximate two and a half month outage for Unit 6 that began in January 2007 and is expected to be completed in early second quarter 2007.

Income from Bruce B is directly impacted by the fluctuations in wholesale spot market prices for electricity.  Income from both Bruce A and Bruce B units is impacted by overall plant availability, which in turn is impacted by scheduled and unscheduled maintenance.  As a result of a contract with the OPA, in first quarter 2006 all of the output from Bruce A was sold at a fixed price of $57.37 per MWh (before recovery of fuel costs from the OPA) and sales from the Bruce B Units 5 to 8 were subject to a floor price of $45 per MWh.  Both of these reference prices are adjusted annually on April 1 for inflation and other potential adjustments in accordance with the terms of the contract with OPA.  Effective April 1, 2006, the Bruce A price is $58.63 per MWh and the Bruce B floor price is $45.99 per MWh.  Payments received pursuant to the Bruce B floor price mechanism may be subject to a recapture payment dependent on annual spot prices over the term of the contract.  Bruce B net earnings included no amounts received pursuant to this floor mechanism to date.  To further reduce its exposure to spot market prices, Bruce B has entered into fixed price sales contracts to sell forward approximately 6,900 GWh of output for 2007.

The capital cost of Bruce A’s four unit, seven year restart and refurbishment project is expected to total approximately $4.25 billion with TransCanada’s share being approximately $2.125 billion.  As at December 31, 2006, Bruce A had incurred $1.092 billion with respect to the restart and refurbishment project.

18



Western Power Operations

Western Power Operations Results-at-a-Glance

 

 

 

 

 

(millions of dollars)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Revenue

 

 

 

 

 

 

 

 

 

Power

 

378

 

235

 

1,185

 

715

 

Other (1)

 

35

 

50

 

169

 

158

 

 

 

413

 

285

 

1,354

 

873

 

Commodity purchases resold

 

 

 

 

 

 

 

 

 

Power

 

(233

)

(163

)

(767

)

(476

)

Other (1)

 

(32

)

(37

)

(135

)

(104

)

 

 

(265

)

(200

)

(902

)

(580

)

Plant operating costs and other

 

(35

)

(47

)

(135

)

(149

)

Depreciation

 

(4

)

(5

)

(20

)

(21

)

Operating income

 

109

 

33

 

297

 

123

 

(1)             Other includes Cancarb Thermax and natural gas sales.

Western Power Operations Sales Volumes

 

 

 

 

 

(GWh)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Supply

 

 

 

 

 

 

 

 

 

Generation

 

637

 

554

 

2,259

 

2,245

 

Purchased

 

 

 

 

 

 

 

 

 

Sundance A & B and Sheerness PPAs

 

3,192

 

1,837

 

12,712

 

6,974

 

Other purchases

 

445

 

684

 

1,905

 

2,687

 

 

 

4,274

 

3,075

 

16,876

 

11,906

 

Contracted vs. Spot

 

 

 

 

 

 

 

 

 

Contracted

 

3,053

 

2,804

 

11,029

 

10,374

 

Spot

 

1,221

 

271

 

5,847

 

1,532

 

 

 

4,274

 

3,075

 

16,876

 

11,906

 

 

Western Power Operations’ operating income of $109 million and $297 million for the three months and year ended December 31, 2006 increased $76 million and $174 million, respectively, compared to the same periods in 2005.  These increases were primarily due to incremental earnings from the December 31, 2005 acquisition of the 756 MW Sheerness PPA and increased margins from a combination of higher overall realized power prices and higher market heat rates on uncontracted volumes of power sold.  The market heat rate is determined by dividing the average price of power per MWh by the average price of natural gas per gigajoule (GJ) for a given period.  Market heat rates in fourth quarter 2006 increased by approximately 70 per cent as a result of an approximate 40 per cent ($4.25 per GJ) decrease in average spot market natural gas prices in Alberta, while average spot market power prices remained relatively unchanged from fourth quarter 2005.  A higher portion of power sales volumes were sold by the company into the spot market in fourth quarter 2006, compared to 2005, due to the acquisition of the Sheerness PPA.  TransCanada manages the sale of its supply volumes on a portfolio basis.  A portion of TransCanada’s supply is held for sale in the spot market for operational reasons and is dependent upon the ability to transact in forward sales markets at acceptable contract terms.  The approach to portfolio management assists in minimizing costs in situations where TransCanada would otherwise have to purchase electricity in the open market to fulfill its contractual sales obligations.

Power revenues and commodity purchases resold increased in fourth quarter 2006, compared to fourth quarter 2005, primarily due to the acquisition of the Sheerness PPA.  Higher overall realized power sales prices in fourth quarter 2006 also increased power revenues.  Generation volumes of 637 GWh in fourth quarter 2006 increased 83 GWh compared to fourth quarter 2005 primarily due to the return to service of the Bear Creek facility in August 2006.  The company’s purchased power volumes and percentage of power volumes sold in the Alberta spot market increased in fourth quarter 2006 compared to 2005 due to the acquisition of the Sheerness PPA.  Approximately 29 per cent of power sales volumes were sold into the spot market in fourth quarter 2006 compared to nine per cent in fourth quarter 2005.  To reduce its exposure to spot market prices on uncontracted volumes, as at December 31, 2006, Western Power Operations had fixed price power sales contracts to sell approximately 10,600 GWh for 2007.

19



Eastern Power Operations

Eastern Power Operations Results-at-a-Glance

 

 

 

 

 

(millions of dollars)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Revenue

 

 

 

 

 

 

 

 

 

Power

 

262

 

125

 

789

 

505

 

Other (1)

 

68

 

158

 

292

 

412

 

 

 

330

 

283

 

1,081

 

917

 

Commodity purchases resold

 

 

 

 

 

 

 

 

 

Power

 

(95

)

(32

)

(379

)

(215

)

Other (1)

 

(61

)

(136

)

(257

)

(373

)

 

 

(156

)

(168

)

(636

)

(588

)

 

 

 

 

 

 

 

 

 

 

Plant operating costs and other

 

(108

)

(40

)

(226

)

(167

)

Depreciation

 

(11

)

(7

)

(32

)

(25

)

Operating income

 

55

 

68

 

187

 

137

 

(1)             Other includes natural gas.

Eastern Power Operations Sales Volumes
(Gwh)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Supply

 

 

 

 

 

 

 

 

 

Generation

 

2,007

 

873

 

4,700

 

2,879

 

Purchased

 

760

 

489

 

3,091

 

2,627

 

 

 

2,767

 

1,362

 

7,791

 

5,506

 

Contracted vs. Spot

 

 

 

 

 

 

 

 

 

Contracted

 

2,659

 

1,154

 

7,374

 

4,919

 

Spot

 

108

 

208

 

417

 

587

 

 

 

2,767

 

362

 

7,791

 

5,506

 

 

Eastern Power Operations’ operating income was $13 million lower in fourth quarter 2006 compared to fourth quarter 2005.  Record hurricane activity in the Gulf of Mexico in 2005 caused a significant increase in certain commodity prices and increased hydro generation volumes. As a result, higher profits were earned in 2005 from increased generation volumes as a result of unusually high water flows through the TC Hydro facilities, increased margins on the natural gas purchased and resold under the OSP gas supply contracts and higher prices realized on power sold into the spot market.  The quarter over quarter decrease was partially offset by incremental income earned in 2006 from the startup of both the 550 MW Bécancour cogeneration plant in September 2006 and the first of six wind farms at the Cartier Wind project in November 2006.

Operating income for the year ended December 31, 2006 was $187 million or $50 million higher than the $137 million earned in the same period of 2005.  This increase was primarily due to incremental income from a full year of ownership of the TC Hydro generation assets acquired April 1, 2005, the placing into service of the 550 MW Bécancour cogeneration plant in September 2006, a $10 million ($16 million pre-tax) one-time restructuring payment in first quarter 2005 from OSP to its natural gas fuel suppliers, and higher overall margins on higher power sales volumes in 2006.  Partially offsetting these increases was the negative impact of a weaker U.S. dollar in 2006 compared to 2005.

Generation volumes in fourth quarter 2006 increased 1,134 GWh to 2,007 GWh compared to 873 GWh in fourth quarter 2005 primarily due to the placing into service of the Bécancour facility.

20



Power revenues of $262 million increased $137 million in fourth quarter 2006, compared to fourth quarter 2005, primarily due to the placing into service of the Bécancour facility, increased sales volumes to commercial and industrial customers and higher realized prices.  Power commodity purchases resold of $95 million was higher in fourth quarter 2006, compared to fourth quarter 2005, primarily due to the impact of increased purchased volumes to supply sales contracts combined with higher power purchase prices.  Purchased power volumes of 760 GWh were higher in fourth quarter 2006 to supply increased sales volumes.  Fourth quarter 2006 other revenue and other commodity purchases resold of $68 million and $61 million, respectively, decreased year-over-year primarily as a result of a reduction in the quantity of natural gas being resold under the OSP natural gas sales contracts and lower gas prices.  Plant operating costs and other in fourth quarter 2006 of $108 million, which includes fuel gas consumed in generation, increased from the prior year primarily as a result of the placing into service of the Bécancour facility.

In fourth quarter 2006, approximately four per cent of power sales volumes were sold into the spot market compared to approximately 15 per cent in fourth quarter 2005.  Eastern Power Operations is focused on selling the majority of its power under contract to wholesale, commercial and industrial customers while managing a portfolio of power supplies sourced from its own generation and wholesale power purchases.  To reduce its exposure to spot market prices, as at December 31, 2006, Eastern Power Operations had entered into fixed price power sales contracts to sell approximately 11,900 GWh for 2007, although certain contracted volumes are dependent on customer usage levels.

23



 

Power Sales Volumes and Plant Availability

Power Sales Volumes
(GWh)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Bruce Power (1)

 

3,469

 

2,946

 

13,317

 

10,732

 

Western Power Operations (2)

 

4,274

 

3,075

 

16,876

 

11,906

 

Eastern Power Operations (3)

 

2,767

 

1,362

 

7,791

 

5,506

 

Power LP Investment (4)

 

—

 

—

 

—

 

1,865

 

Total

 

10,510

 

7,383

 

37,984

 

30,009

 

(1)             Sales volumes reflect TransCanada’s proportionate share of Bruce Power output.

(2)             The Sheerness PPA volumes are included in Western Power Operations effective December 31, 2005.

(3)             TC Hydro, Bécancour and Phase I of Cartier are included in Eastern Power Operations effective April 1, 2005, September 17, 2006 and November 21, 2006, respectively.

(4)             TransCanada operated and managed Power LP until August 31, 2005. The volumes in the table represent 100 per cent of Power LP’s sales volumes to August 31, 2005.

Weighted Average Plant Availability (1)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

Bruce Power

 

89

%

79

%

88

%

80

%

Western Power Operations (2)

 

92

%

81

%

88

%

85

%

Eastern Power Operations (3)

 

89

%

90

%

95

%

83

%

Power LP investment (4)

 

—

 

—

 

—

 

94

%

All plants, excluding Bruce Power investment

 

90

%

88

%

93

%

87

%

All plants

 

90

%

84

%

91

%

84

%

(1)           Plant availability represents the percentage of time in the period that the plant is available to generate power, whether actually running or not and is reduced by planned and unplanned outages.

(2)           The Sheerness PPA is included in Western Power Operations, effective December 31, 2005.

(3)           TC Hydro, Bécancour and Phase I of Cartier are included in Eastern Power Operations effective April 1, 2005, September 17, 2006 and November 21, 2006, respectively.

(4)           Power LP is included to August 31, 2005.

Natural Gas Storage

Natural Gas Storage operating income of $30 million and $93 million for the three months and year ended December 31, 2006, increased $13 million and $61 million, respectively, compared to the same periods in 2005.  These increases were primarily due to higher earnings from CrossAlta as a result of increased capacity, higher natural gas storage spreads, and income from other contracted third party natural gas storage capacity in Alberta.  Commissioning of the Edson natural gas storage facility in Alberta took place in fourth quarter 2006 and the facility was placed into service on December 31, 2006.

General, Administrative and Support Costs

General, administrative and support costs of $44 million and $144 million for the three months and year ended December 31, 2006, respectively, increased $8 million and $15 million compared to the same periods in 2005.  The increases were primarily due to higher costs associated with growing the Energy business.

As at December 31, 2006, TransCanada had capitalized $31 million related to the Broadwater LNG project.

24



 

Corporate

Net earnings from Corporate for the three months and year ended December 31, 2006 were $11 million and $39 million, respectively, compared to net expenses of $7 million and $36 million for the corresponding periods in 2005.

The $18 million increase in net earnings for fourth quarter 2006, compared to the same period in 2005, was primarily due to $12 million in income tax refunds and related interest and other positive income tax adjustments.  Partially offsetting these increases in net earnings was higher financial charges, including higher interest expense as a result of long-term debt issued in 2006.

The $75 million increase in net earnings for the year ended December 31, 2006, compared to the same period in 2005, was primarily due to the $12 million in income tax refunds and related interest recorded in fourth quarter 2006, a $50 million income tax benefit related to the resolution of certain income tax matters reported in third quarter 2006, and a $10 million favourable impact on future income taxes arising from reductions in Canadian federal and provincial corporate income tax rates reported in second quarter 2006.  In addition, net earnings in 2006 were positively impacted by the effect of a weaker U.S. dollar.

Other Recent Developments

Additional recent developments are discussed at the beginning of this news release.

Pipelines

Canadian Mainline

On November 23, 2006, the NEB announced that, pursuant to the adjustment mechanism approved in the Multi-Pipeline Cost of Capital Decision (RH-2-94), the Canadian Mainline’s ROE for 2007 is 8.46 per cent, a reduction from the 2006 ROE of 8.88 per cent.

TransCanada is addressing pipeline requirements related to the proposed Cacouna LNG terminal and filed an application, in December 2006, with the NEB for a new receipt point at Gros Cacouna and to affirm the tolling methodology that will apply to service from that point.

Alberta System

On November 30, 2006, the Alberta Energy and Utilities Board (EUB) announced that the Alberta System’s formula-based ROE for 2007 is 8.51 per cent, a reduction from the 2006 ROE of 8.93 per cent. On December 20, 2006, the EUB approved TransCanada’s application to charge interim tolls for transportation service, effective January 1, 2007.  Final tolls for 2007 are expected to be determined in the first quarter of 2007.

Foothills System

On December 21, 2006, TransCanada filed an application with the NEB for the integration of the BC System with the Foothills System.  TransCanada seeks to sell the BC System facilities to Foothills South B.C.  Foothills South B.C. intends to acquire and incorporate the facilities into its existing system and provide the same services currently provided to shippers on the BC System.  This transaction is expected to result in reduced operating costs through increased administrative efficiencies.

Gas Transmission Northwest System

In June 2006, the Gas Transmission Northwest System filed a rate case with the FERC.  The comprehensive filing requested a number of tariff changes, including an increase in transportation rates that became effective January 1, 2007, subject to refund.  The rates in effect prior to the January 2007 rate increase resulted from the resolution of the system’s last rate case which was filed in 1994.  The new rates reflect an ROE of 14.5 per cent, a common equity ratio of 62.99 per cent and a depreciation rate for the transmission plant of 2.76 per cent.

The company received a procedural order from the FERC in January 2007, which established the timeline for its rate case proceedings. The rate case hearing is currently scheduled to commence in October 2007.

North Baja Pipeline Expansion

On February 7, 2006, TransCanada’s North Baja Pipeline filed an application with the FERC to expand and modify its existing system to facilitate the importation of up to 2.7 Bcf/d of regassified LNG from Mexico into the California and Arizona markets.  Specifically, North Baja proposes to modify its existing system to accommodate bi-directional natural gas flow, as well as construct new pipeline and metering facilities. On October 6, 2006, the FERC issued a preliminary determination approving all aspects of North Baja’s proposal other than those related to environmental issues, which will be the subject of a future order.

25



 

Northern Border

In September 2006, Northern Border reached a settlement with its participant customers regarding its pending rate case before the FERC.  The settlement, which establishes maximum long-term rates and charges for transportation on the Northern Border system, and is supported by the FERC trial staff, was certified by the administrative law judge presiding over the case and approved by the FERC on November 21, 2006.

Energy

Forward Capacity Market

On June 15, 2006, the FERC approved a settlement agreement to implement a newly designed Forward Capacity Market (FCM) for power generation in the New England power markets.  The FCM design is intended to promote investment in new and existing power resources needed to meet the growing consumer demand and maintain a reliable power system.  The settlement agreement provides for a multi-year transition period beginning in December 2006 and ending in 2010 whereby fixed payments, ranging from US$3.05 to US$4.10 per kilowatt-month, will be made to owners of existing installed capacity.  These payments will be reduced in the event of facility outages.  Eastern Power Operations’ 560 MW OSP plant and 567 MW TC Hydro generation facilities are eligible to receive payments during the transition period starting in December 2006.  Under the new FCM design, Independent System Operator (ISO) New England will project the needs of the power system three years in advance and then hold an annual auction to purchase power resources to satisfy a region’s future needs.  June 2010 is the first date for which suppliers would begin receiving payments pursuant to the FCM auction mechanism.

Broadwater

In November 2006, the Broadwater Energy project reached another major milestone when the FERC released the Draft Environmental Impact Statement (DEIS) for Broadwater’s proposed offshore LNG facility in Long Island Sound. In the DEIS, the FERC concluded that additional natural gas supply is needed for electrical generation and to meet air quality objectives, and that the Broadwater project, with the adoption of the FERC and U.S. Coast Guard recommendations, would result in fewer environmental impacts than any alternatives considered.  TransCanada anticipates that the FERC will issue a Final Environmental Impact Statement in 2007.  Pending regulatory approvals, the first delivery of LNG to the Broadwater terminal is expected in late 2010.  Broadwater is a partnership between TransCanada and Shell US Gas & Power.

Cacouna

The Cacouna Energy project took another step forward in December 2006 with the release of the report by the Bureau d’audiences publiques sur l’environnement (BAPE) and the Canadian Environmental Assessment Agency (CEAA) joint review panel on the proposed LNG terminal in Gros Cacouna, Québec.  The panel concluded that the project is not likely to cause significant adverse environmental effects if the mitigation measures and recommendations made by the panel are implemented.  Cacouna is a partnership between TransCanada and Petro-Canada and, pending regulatory approvals, the partners anticipate beginning construction activities on the LNG terminal in 2007.

Corporate

Eligible Dividends

All dividends paid by TransCanada and TCPL after December 31, 2005, and received by a person resident in Canada, will be an ‘eligible dividend’ for purposes of the Income Tax Act (Canada), on enactment of proposed legislation dated October 16, 2006.  Under this legislation, on receipt of an eligible dividend, an individual resident in Canada is entitled to an enhanced dividend tax credit.

26



 

Consolidated Income

(millions of dollars except per share amounts)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

2,091

 

1,771

 

7,520

 

6,124

 

 

 

 

 

 

 

 

 

 

 

Operating Expenses

 

 

 

 

 

 

 

 

 

Plant operating costs and other

 

715

 

546

 

2,411

 

1,825

 

Commodity purchases resold

 

483

 

398

 

1,707

 

1,232

 

Depreciation

 

272

 

265

 

1,059

 

1,017

 

 

 

1,470

 

1,209

 

5,177

 

4,074

 

 

 

 

 

 

 

 

 

 

 

 

 

621

 

562

 

2,343

 

2,050

 

 

 

 

 

 

 

 

 

 

 

Other Expenses/(Income)

 

 

 

 

 

 

 

 

 

Financial charges

 

213

 

211

 

825

 

836

 

Financial charges of joint ventures

 

25

 

17

 

92

 

66

 

Income from equity investments

 

(5

)

(51

)

(33

)

(247

)

Interest income and other

 

(27

)

(14

)

(123

)

(63

)

Gain on sale of Northern Border Partners, L.P. interest

 

—

 

—

 

(23

)

—

 

Gain on sale of Paiton Energy

 

—

 

(118

)

—

 

(118

)

Gains related to Power LP

 

—

 

—

 

—

 

(245

)

Gain on sale of PipeLines LP units

 

—

 

—

 

—

 

(82

)

 

 

206

 

45

 

738

 

147

 

 

 

 

 

 

 

 

 

 

 

Income from Continuing Operations before Income Taxes and Non-Controlling Interests

 

415

 

517

 

1,605

 

1,903

 

 

 

 

 

 

 

 

 

 

 

Income Taxes

 

 

 

 

 

 

 

 

 

Current

 

23

 

121

 

301

 

550

 

Future

 

104

 

22

 

175

 

60

 

 

 

127

 

143

 

476

 

610

 

 

 

 

 

 

 

 

 

 

 

Non-Controlling Interests

 

 

 

 

 

 

 

 

 

Preferred share dividends of subsidiary

 

5

 

5

 

22

 

22

 

Non-controlling interest in PipeLines LP

 

11

 

16

 

43

 

52

 

Other

 

3

 

3

 

13

 

10

 

 

 

19

 

24

 

78

 

84

 

Net Income from Continuing Operations

 

269

 

350

 

1,051

 

1,209

 

Net Income from Discontinued Operations

 

—

 

—

 

28

 

—

 

Net Income

 

269

 

350

 

1,079

 

1,209

 

 

 

 

 

 

 

 

 

 

 

Net Income Per Share

 

 

 

 

 

 

 

 

 

Basic

 

 

 

 

 

 

 

 

 

Continuing operations

 

$

0.55

 

$

0.72

 

$

2.15

 

$

2.49

 

Discontinued operations

 

—

 

—

 

0.06

 

—

 

 

 

$

0.55

 

$

0.72

 

$

2.21

 

$

2.49

 

Diluted

 

 

 

 

 

 

 

 

 

Continuing operations

 

$

0.54

 

$

0.71

 

$

2.14

 

$

2.47

 

Discontinued operations

 

—

 

—

 

0.06

 

—

 

 

 

$

0.54

 

$

0.71

 

$

2.20

 

$

2.47

 

Average Shares Outstanding (millions)

 

 

 

 

 

 

 

 

 

Basic

 

488.6

 

487.1

 

488.0

 

486.2

 

Diluted

 

490.9

 

490.4

 

490.6

 

489.1

 

 

27



 

Consolidated Cash Flows

(millions of dollars)

 

Three months ended December 31

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

 

 

 

 

 

 

 

 

 

 

Cash Generated From Operations

 

 

 

 

 

 

 

 

 

Net income

 

269

 

350

 

1,079

 

1,209

 

Depreciation

 

272

 

265

 

1,059

 

1,017

 

Gain on sale of Northern Border Partners, L.P. interest, net of current tax

 

—

 

—

 

(11

)

—

 

Gain on sale of Paiton Energy, net of current tax

 

—

 

(121

)

—

 

(121

)

Gain on sale of PipeLines LP units, net of current tax

 

—

 

—

 

—

 

(31

)

Gains related to Power LP, net of current tax

 

—

 

—

 

—

 

(166

)

Income from equity investments in excess of distributions received

 

(1

)

(1

)

(9

)

(71

)

Future income taxes

 

104

 

22

 

175

 

60

 

Non-controlling interests

 

19

 

24

 

78

 

84

 

Funding of employee future benefits in excess of expense

 

(14

)

(4

)

(31

)

(9

)

Other

 

11

 

(5

)

38

 

(21

)

 

 

660

 

530

 

2,378

 

1,951

 

(Increase)/decrease in operating working capital

 

(167

)

124

 

(303

)

(49

)

Net cash provided by operations

 

493

 

654

 

2,075

 

1,902

 

 

 

 

 

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

 

 

 

 

Capital expenditures

 

(570

)

(345

)

(1,572

)

(754

)

Acquisitions, net of cash acquired

 

(112

)

(685

)

(470

)

(1,317

)

Disposition of assets, net of current tax

 

—

 

125

 

23

 

671

 

Deferred amounts and other

 

(34

)

(29

)

(97

)

64

 

Net cash used in investing activities

 

(716

)

(934

)

(2,116

)

(1,336

)

 

 

 

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

 

 

 

 

Dividends on common shares

 

(156

)

(148

)

(617

)

(586

)

Distributions paid to non-controlling interests

 

(25

)

(12

)

(72

)

(74

)

Notes payable (repaid)/issued, net

 

(46

)

579

 

(495

)

416

 

Long-term debt issued

 

857

 

—

 

2,107

 

799

 

Reduction of long-term debt

 

(377

)

(151

)

(729

)

(1,113

)

Long-term debt of joint ventures issued

 

18

 

33

 

56

 

38

 

Reduction of long-term debt of joint ventures

 

(22

)

(61

)

(70

)

(80

)

Common shares issued

 

14

 

5

 

39

 

44

 

Net cash provided by/(used in) financing activities

 

263

 

245

 

219

 

(556

)

 

 

 

 

 

 

 

 

 

 

Effect of Foreign Exchange Rate Changes on Cash and Short-Term Investments

 

17

 

1

 

9

 

11

 

 

 

 

 

 

 

 

 

 

 

Increase/(Decrease) in Cash and Short-Term Investments

 

57

 

(34

)

187

 

21

 

 

 

 

 

 

 

 

 

 

 

Cash and Short-Term Investments

 

 

 

 

 

 

 

 

 

Beginning of period

 

342

 

246

 

212

 

191

 

 

 

 

 

 

 

 

 

 

 

Cash and Short-Term Investments

 

 

 

 

 

 

 

 

 

End of period

 

399

 

212

 

399

 

212

 

 

28



 

Consolidated Balance Sheet

(millions of dollars)

 

 

 

 

 

(unaudited)

 

December 31, 2006

 

December 31, 2005

 

 

 

 

 

 

 

ASSETS

 

 

 

 

 

Current Assets

 

 

 

 

 

Cash and short-term investments

 

399

 

212

 

Accounts receivable

 

1,004

 

796

 

Inventories

 

392

 

281

 

Other

 

297

 

277

 

 

 

2,092

 

1,566

 

Long-Term Investments

 

71

 

400

 

Plant, Property and Equipment

 

21,487

 

20,038

 

Goodwill

 

281

 

57

 

Other Assets

 

1,978

 

2,052

 

 

 

25,909

 

24,113

 

 

 

 

 

 

 

LIABILITIES AND SHAREHOLDERS’ EQUITY

 

 

 

 

 

Current Liabilities

 

 

 

 

 

Notes payable

 

467

 

962

 

Accounts payable

 

1,500

 

1,494

 

Accrued interest

 

264

 

222

 

Current portion of long-term debt

 

616

 

393

 

Current portion of long-term debt of joint ventures

 

142

 

41

 

 

 

2,989

 

3,112

 

Deferred Amounts

 

1,029

 

1,196

 

Future Income Taxes

 

876

 

703

 

Long-Term Debt

 

10,887

 

9,640

 

Long-Term Debt of Joint Ventures

 

1,136

 

937

 

Preferred Securities

 

536

 

536

 

 

 

17,453

 

16,124

 

Non-Controlling Interests

 

 

 

 

 

Preferred shares of subsidiary

 

389

 

389

 

Non-controlling interest in PipeLines LP

 

287

 

318

 

Other

 

79

 

76

 

 

 

755

 

783

 

Shareholders’ Equity

 

 

 

 

 

Common shares

 

4,794

 

4,755

 

Contributed surplus

 

273

 

272

 

Retained earnings

 

2,724

 

2,269

 

Foreign exchange adjustment

 

(90

)

(90

)

 

 

7,701

 

7,206

 

 

 

25,909

 

24,113

 

 

29



 

Consolidated Retained Earnings

(millions of dollars)

 

Year ended December 31

 

(unaudited)

 

2006

 

2005

 

Balance at beginning of year

 

2,269

 

1,655

 

Net income

 

1,079

 

1,209

 

Common share dividends

 

(624

)

(595

)

 

 

 

 

 

 

 

 

2,724

 

2,269

 

 

30



 

Segmented Information

Effective June 1, 2006, TransCanada revised the composition and names of its reportable business segments to Pipelines and Energy.  The financial reporting of these segments was aligned to reflect the internal organizational structure of the company.  Pipelines is principally comprised of the company’s pipelines in Canada, the United States and Mexico.  Energy includes the company’s power operations, natural gas storage business and LNG projects in Canada and the United States.  The segmented information has been retroactively restated to reflect the changes in reportable segments.  These changes had no impact on consolidated net income.

The impacts on segment net income of each of Pipelines and Energy in each quarter of 2005 and first quarter 2006 are as follows.

 

2005

 

2006

 

(unaudited - millions of dollars)

 

First

 

Second

 

Third

 

Fourth

 

Total

 

First

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pipelines

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Income - previously reported as Gas Transmission

 

211

 

165

 

148

 

160

 

684

 

168

 

Reclassifications:

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas storage

 

(4

)

(1

)

(2

)

(9

)

(16

)

(13

)

Costs related to LNG

 

2

 

2

 

3

 

4

 

11

 

2

 

Net Income - revised

 

209

 

166

 

149

 

155

 

679

 

157

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Energy

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Income - previously reported as Power

 

30

 

42

 

292

 

197

 

561

 

89

 

Reclassifications:

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas storage

 

4

 

1

 

2

 

9

 

16

 

13

 

Costs related to LNG

 

(2

)

(2

)

(3

)

(4

)

(11

)

(2

)

Net Income - revised

 

32

 

41

 

291

 

202

 

566

 

100

 

 

 

Three months ended December 31

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(millions of dollars)

 

Pipelines

 

Energy

 

Corporate

 

Total

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

2006

 

2005

 

2006

 

2005

 

Revenues

 

1,034

 

1,012

 

1,057

 

759

 

—

 

—

 

2,091

 

1,771

 

Plant operating costs and other

 

(386

)

(327

)

(329

)

(219

)

—

 

—

 

(715

)

(546

)

Commodity purchases resold

 

—

 

—

 

(483

)

(398

)

—

 

—

 

(483

)

(398

)

Depreciation

 

(235

)

(232

)

(36

)

(33

)

(1

)

—

 

(272

)

(265

)

 

 

413

 

453

 

209

 

109

 

(1

)

—

 

621

 

562

 

Financial charges and non-controlling interests

 

(194

)

(200

)

—

 

—

 

(38

)

(35

)

(232

)

(235

)

Financial charges of joint ventures

 

(19

)

(13

)

(6

)

(4

)

—

 

—

 

(25

)

(17

)

Income from equity investments

 

5

 

25

 

—

 

26

 

—

 

—

 

5

 

51

 

Interest income and other

 

8

 

4

 

—

 

—

 

19

 

10

 

27

 

14

 

Gain on sale of Paiton Energy

 

—

 

—

 

—

 

118

 

—

 

—

 

—

 

118

 

Income taxes

 

(87

)

(114

)

(71

)

(47

)

31

 

18

 

(127

)

(143

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Continuing Operations

 

126

 

155

 

132

 

202

 

11

 

(7

)

269

 

350

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Discontinued Operations

 

 

 

 

 

 

 

 

 

 

 

 

 

—

 

—

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

 

 

 

 

 

 

 

 

 

 

 

 

269

 

350

 

 

31



 

Year ended December 31

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(millions of dollars)

 

Pipelines

 

Energy

 

Corporate

 

Total

 

(unaudited)

 

2006

 

2005

 

2006

 

2005

 

2006

 

2005

 

2006

 

2005

 

Revenues

 

3,990

 

3,993

 

3,530

 

2,131

 

—

 

—

 

7,520

 

6,124

 

Plant operating costs and other

 

(1,380

)

(1,226

)

(1,024

)

(595

)

(7

)

(4

)

(2,411

)

(1,825

)

Commodity purchases resold

 

—

 

—

 

(1,707

)

(1,232

)

—

 

—

 

(1,707

)

(1,232

)

Depreciation

 

(927

)

(932

)

(131

)

(85

)

(1

)

—

 

(1,059

)

(1,017

)

 

 

1,683

 

1,835

 

668

 

219

 

(8

)

(4

)

2,343

 

2,050

 

Financial charges and non-controlling interests

 

(767

)

(788

)

—

 

(2

)

(136

)

(130

)

(903

)

(920

)

Financial charges of joint ventures

 

(69

)

(57

)

(23

)

(9

)

—

 

—

 

(92

)

(66

)

Income from equity investments

 

33

 

79

 

—

 

168

 

—

 

—

 

33

 

247

 

Interest income and other

 

67

 

25

 

5

 

5

 

51

 

33

 

123

 

63

 

Gain on sale of Northern Border Partners, L.P. interest

 

23

 

—

 

—

 

—

 

—

 

—

 

23

 

—

 

Gain on sale of Paiton Energy

 

—

 

—

 

—

 

118

 

—

 

—

 

—

 

118

 

Gains related to Power LP

 

—

 

—

 

—

 

245

 

—

 

—

 

—

 

245

 

Gain on sale of PipeLines LP units

 

—

 

82

 

—

 

—

 

—

 

—

 

—

 

82

 

Income taxes

 

(410

)

(497

)

(198

)

(178

)

132

 

65

 

(476

)

(610

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Continuing Operations

 

560

 

679

 

452

 

566

 

39

 

(36

)

1,051

 

1,209

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Discontinued Operations

 

 

 

 

 

 

 

 

 

 

 

 

 

28

 

—

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

 

 

 

 

 

 

 

 

 

 

 

 

1,079

 

1,209

 

 

 

Teleconference

TransCanada will hold a teleconference today at 1 p.m. (Mountain) / 3 p.m. (Eastern) to discuss the fourth quarter 2006 financial results and general developments and issues concerning the company. Analysts, members of the media and other interested parties wanting to participate should phone 1-866-898-9626 or 416-340-2216 (Toronto area) at least 10 minutes prior to the start of the teleconference. No passcode is required. A live webcast of the teleconference will also be available on TransCanada’s website at www.transcanada.com.

The conference will begin with a short address by members of TransCanada’s executive management, followed by a question and answer period for investment analysts. A question and answer period for members of the media will immediately follow.

A replay of the teleconference will be available two hours after the conclusion of the call until midnight (Eastern) February 6, 2007. Please call (800) 408-3053 or (416) 695-5800 (Toronto area) and enter pass code 3210334. The webcast will be archived and available for replay on www.transcanada.com.

About TransCanada

TransCanada is a leader in the responsible development and reliable operation of North American energy infrastructure including natural gas pipelines and storage facilities, and power generation. For 50 years, TransCanada has transported the majority of Western Canada’s natural gas production to key Canadian and U.S. markets. On closing of the acquisition of the ANR Pipeline Company and ANR Storage Company announced December 22, 2006, TransCanada’s network of wholly owned pipelines will extend more than 59,000 km (36,500 miles), tapping into virtually all major gas supply basins in North America. TransCanada will also become one of the continent’s largest providers of gas storage and related services with approximately 360 Bcf of storage capacity. A growing independent power producer, TransCanada owns, or has interests in, approximately 7,700 MW of power generation in Canada and the United States. TransCanada’s common shares trade on the Toronto and New York stock exchanges under the symbol TRP.

TransCanada welcomes questions from shareholders and potential investors. Please telephone:

Investor Relations, at 1-800-361-6522 (Canada and U.S. Mainland) or direct dial David Moneta/Myles Dougan at (403) 920-7911. The investor fax line is (403) 920-2457. Media Relations: Jennifer Varey at (403) 920-7859 or Sheila Shapiro at (403)920-2240

Visit TransCanada’s Internet site at: http://www.transcanada.com

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