Exhibit 13.2
Consolidated Income
(unaudited) |
| Three months ended June 30 |
| Six months ended June 30 |
| ||||
(millions of dollars except per share amounts) |
| 2007 |
| 2006 |
| 2007 |
| 2006 |
|
|
|
|
|
|
|
|
|
|
|
Revenues |
| 2,212 |
| 1,685 |
| 4,461 |
| 3,579 |
|
|
|
|
|
|
|
|
|
|
|
Operating Expenses |
|
|
|
|
|
|
|
|
|
Plant operating costs and other |
| 761 |
| 566 |
| 1,493 |
| 1,103 |
|
Commodity purchases resold |
| 527 |
| 337 |
| 1,103 |
| 842 |
|
Depreciation |
| 300 |
| 266 |
| 590 |
| 523 |
|
|
| 1,588 |
| 1,169 |
| 3,186 |
| 2,468 |
|
|
| 624 |
| 516 |
| 1,275 |
| 1,111 |
|
Other Expenses/(Income) |
|
|
|
|
|
|
|
|
|
Financial charges |
| 264 |
| 207 |
| 501 |
| 409 |
|
Financial charges of joint ventures |
| 19 |
| 24 |
| 40 |
| 45 |
|
Income from equity investments |
| (5) |
| (6) |
| (11) |
| (24) |
|
Interest income and other |
| (43) |
| (15) |
| (68) |
| (64) |
|
Gain on sale of Northern Border Partners, L.P. interest |
| - |
| (23) |
| - |
| (23) |
|
|
| 235 |
| 187 |
| 462 |
| 343 |
|
|
|
|
|
|
|
|
|
|
|
Income from Continuing Operations before Income |
| 389 |
| 329 |
| 813 |
| 768 |
|
|
|
|
|
|
|
|
|
|
|
Current |
| 96 |
| 37 |
| 264 |
| 247 |
|
Future |
| 16 |
| 37 |
| (21) |
| (4) |
|
|
| 112 |
| 74 |
| 243 |
| 243 |
|
|
|
|
|
|
|
|
|
|
|
Non-Controlling Interests |
|
|
|
|
|
|
|
|
|
Preferred share dividends of subsidiary |
| 5 |
| 5 |
| 11 |
| 11 |
|
Non-controlling interest in PipeLines LP |
| 14 |
| 8 |
| 31 |
| 21 |
|
Other |
| 1 |
| (2) |
| 6 |
| 4 |
|
|
| 20 |
| 11 |
| 48 |
| 36 |
|
|
|
|
|
|
|
|
|
|
|
Net Income from Continuing Operations |
| 257 |
| 244 |
| 522 |
| 489 |
|
Net Income from Discontinued Operations |
| - |
| - |
| - |
| 28 |
|
Net Income |
| 257 |
| 244 |
| 522 |
| 517 |
|
|
|
|
|
|
|
|
|
|
|
Net Income Per Share |
|
|
|
|
|
|
|
|
|
Continuing operations |
| $0.48 |
| $0.50 |
| $1.00 |
| $1.00 |
|
Discontinued operations |
| - |
| - |
| - |
| 0.06 |
|
Basic and Diluted |
| $0.48 |
| $0.50 |
| $1.00 |
| $1.06 |
|
|
|
|
|
|
|
|
|
|
|
Average Shares Outstanding - Basic (millions) |
| 536 |
| 488 |
| 522 |
| 488 |
|
|
| 538 |
| 490 |
| 525 |
| 490 |
|
See accompanying notes to the consolidated financial statements.
Consolidated Cash Flows
(unaudited) |
| Three months ended June 30 |
| Six months ended June 30 |
| ||||
(millions of dollars) |
| 2007 |
| 2006 |
| 2007 |
| 2006 |
|
|
|
|
|
|
|
|
|
|
|
Cash Generated From Operations |
|
|
|
|
|
|
|
|
|
Net income |
| 257 |
| 244 |
| 522 |
| 517 |
|
Depreciation |
| 300 |
| 266 |
| 590 |
| 523 |
|
Gain on sale of Northern Border Partners, L.P. interest, net of |
|
|
|
|
|
|
|
|
|
current income tax |
| - |
| (11) |
| - |
| (11) |
|
Income from equity investments lower than/(in excess of) |
| 1 |
| (3) |
| (5) |
| (7) |
|
distributions received |
|
|
|
|
|
|
|
|
|
Future income taxes |
| 16 |
| 37 |
| (21) |
| (4) |
|
Non-controlling interests |
| 20 |
| 11 |
| 48 |
| 36 |
|
Funding of employee future benefits lower than/(in excess of) |
| 3 |
| (13) |
| 15 |
| (15) |
|
expense |
|
|
|
|
|
|
|
|
|
Other |
| (1) |
| 8 |
| 29 |
| 17 |
|
|
| 596 |
| 539 |
| 1,178 |
| 1,056 |
|
Decrease/(increase) in operating working capital |
| 93 |
| (91) |
| 129 |
| (93) |
|
Net cash provided by operations |
| 689 |
| 448 |
| 1,307 |
| 963 |
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures |
| (386) |
| (327) |
| (692) |
| (630) |
|
Acquisitions, net of cash acquired |
| (4) |
| (358) |
| (4,224) |
| (358) |
|
Disposition of assets, net of current income taxes |
| - |
| 23 |
| - |
| 23 |
|
Deferred amounts and other |
| (5) |
| (7) |
| (111) |
| (16) |
|
Net cash used in investing activities |
| (395) |
| (669) |
| (5,027) |
| (981) |
|
|
|
|
|
|
|
|
|
|
|
Financing Activities |
|
|
|
|
|
|
|
|
|
Dividends on common shares |
| (182) |
| (156) |
| (338) |
| (305) |
|
Distributions paid to non-controlling interests |
| (29) |
| (15) |
| (45) |
| (31) |
|
Notes payable (repaid)/issued, net |
| (804) |
| 180 |
| 261 |
| (453) |
|
Long-term debt issued |
| 52 |
| 372 |
| 1,414 |
| 1,250 |
|
Reduction of long-term debt |
| (470) |
| (208) |
| (795) |
| (348) |
|
Long-term debt of joint ventures issued |
| 98 |
| 22 |
| 110 |
| 24 |
|
Reduction of long-term debt of joint ventures |
| (107) |
| (15) |
| (119) |
| (21) |
|
Junior subordinated notes issued |
| 1,107 |
| - |
| 1,107 |
| - |
|
Partnership units of subsidiary issued |
| - |
| - |
| 348 |
| - |
|
Common shares issued |
| 58 |
| 5 |
| 1,748 |
| 13 |
|
Net cash (used in)/provided by financing activities |
| (277) |
| 185 |
| 3,691 |
| 129 |
|
|
|
|
|
|
|
|
|
|
|
Effect of Foreign Exchange Rate Changes on Cash and |
|
|
|
|
|
|
|
|
|
Short-Term Investments |
| (27) |
| (11) |
| (30) |
| (9) |
|
|
|
|
|
|
|
|
|
|
|
(Decrease)/Increase in Cash and Short-Term Investments |
| (10) |
| (47) |
| (59) |
| 102 |
|
|
|
|
|
|
|
|
|
|
|
Cash and Short-Term Investments |
|
|
|
|
|
|
|
|
|
Beginning of period |
| 350 |
| 361 |
| 399 |
| 212 |
|
|
|
|
|
|
|
|
|
|
|
Cash and Short-Term Investments |
|
|
|
|
|
|
|
|
|
End of period |
| 340 |
| 314 |
| 340 |
| 314 |
|
|
|
|
|
|
|
|
|
|
|
Supplementary Cash Flow Information |
|
|
|
|
|
|
|
|
|
Income taxes paid |
| 125 |
| 151 |
| 212 |
| 368 |
|
Interest paid |
| 269 |
| 224 |
| 542 |
| 434 |
|
See accompanying notes to the consolidated financial statements.
Consolidated Balance Sheet
(unaudited) |
| June 30, |
| December 31, |
|
(millions of dollars) |
| 2007 |
| 2006 |
|
|
|
|
|
|
|
Current Assets |
|
|
|
|
|
Cash and short-term investments |
| 340 |
| 399 |
|
Accounts receivable |
| 983 |
| 1,004 |
|
Inventories |
| 466 |
| 392 |
|
Other |
| 187 |
| 297 |
|
|
| 1,976 |
| 2,092 |
|
Long-Term Investments |
| 69 |
| 71 |
|
Plant, Property and Equipment |
| 23,700 |
| 21,487 |
|
Goodwill |
| 2,682 |
| 281 |
|
Other Assets |
| 1,895 |
| 1,978 |
|
|
| 30,322 |
| 25,909 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Liabilities |
|
|
|
|
|
Notes payable |
| 728 |
| 467 |
|
Accounts payable |
| 1,616 |
| 1,500 |
|
Accrued interest |
| 265 |
| 264 |
|
Current portion of long-term debt |
| 759 |
| 616 |
|
Current portion of long-term debt of joint ventures |
| 32 |
| 142 |
|
|
| 3,400 |
| 2,989 |
|
Deferred Amounts |
| 1,143 |
| 1,029 |
|
Future Income Taxes |
| 1,186 |
| 876 |
|
Long-Term Debt |
| 11,766 |
| 10,887 |
|
Long-Term Debt of Joint Ventures |
| 913 |
| 1,136 |
|
Junior Subordinated Notes |
| 1,050 |
| - |
|
Preferred Securities |
| 489 |
| 536 |
|
|
| 19,947 |
| 17,453 |
|
Non-Controlling Interests |
|
|
|
|
|
Preferred shares of subsidiary |
| 389 |
| 389 |
|
Non-controlling interest in PipeLines LP |
| 574 |
| 287 |
|
Other |
| 72 |
| 79 |
|
|
| 1,035 |
| 755 |
|
Shareholders’ Equity |
|
|
|
|
|
Common shares |
| 6,542 |
| 4,794 |
|
Contributed surplus |
| 275 |
| 273 |
|
Retained earnings |
| 2,892 |
| 2,724 |
|
Accumulated other comprehensive loss |
| (369) |
| (90) |
|
|
| 2,523 |
| 2,634 |
|
|
| 9,340 |
| 7,701 |
|
|
| 30,322 |
| 25,909 |
|
See accompanying notes to the consolidated financial statements.
Consolidated Comprehensive Income
(unaudited) |
| Three months ended June 30 |
| Six months ended June 30 |
| ||||
(millions of dollars) |
| 2007 |
| 2006 |
| 2007 |
| 2006 |
|
Net income |
| 257 |
| 244 |
| 522 |
| 517 |
|
Other comprehensive loss, net of tax |
|
|
|
|
|
|
|
|
|
Change in foreign currency translation gains and losses on investments in foreign operations (1) |
| (184) |
| (29) |
| (221) |
| (30) |
|
Change in gains and losses on hedges of investments in foreign operations (2) |
| 46 |
| 27 |
| 55 |
| 24 |
|
Change in gains and losses on derivative instruments designated as cash flow hedges (3) |
| (36) |
| - |
| (37) |
| - |
|
Reclassification to net income of gains and losses on derivative instruments designated as cash flow hedges pertaining to prior periods (4) |
| 23 |
| - |
| 20 |
| - |
|
Other comprehensive loss for the period |
| (151) |
| (2) |
| (183) |
| (6) |
|
Comprehensive income for the period |
| 106 |
| 242 |
| 339 |
| 511 |
|
(1) Net of tax expense of $51 million and $56 million for the three and six months ended June 30, 2007 (2006 - $23 million and $22
million expense, respectively).
(2) Net of tax expense of $23 million and $28 million for the three and six months ended June 30, 2007 (2006 - $14 million and $12
million expense, respectively).
(3) Net of tax recovery of $15 million and $10 million for the three and six months ended June 30, 2007.
(4) Net of tax expense of $7 million and $5 million for the three and six months ended June 30, 2007.
See accompanying notes to the consolidated financial statements.
Consolidated Shareholders’ Equity
Six months ended June 30 |
|
|
|
|
|
(unaudited) |
|
|
|
|
|
(millions of dollars) |
| 2007 |
| 2006 |
|
Common Shares |
|
|
|
|
|
Balance at beginning of period |
| 4,794 |
| 4,755 |
|
Proceeds from shares issued under public offering (1) |
| 1,683 |
| - |
|
Proceeds from shares issued under dividend reinvestment plan |
| 51 |
| - |
|
Proceeds from shares issued on exercise of stock options |
| 14 |
| 13 |
|
Balance at end of period |
| 6,542 |
| 4,768 |
|
|
|
|
|
|
|
Contributed Surplus |
|
|
|
|
|
Balance at beginning of period |
| 273 |
| 272 |
|
Issuance of stock options |
| 2 |
| 1 |
|
Balance at end of period |
| 275 |
| 273 |
|
|
|
|
|
|
|
Retained Earnings |
|
|
|
|
|
Balance at beginning of period |
| 2,724 |
| 2,269 |
|
Transition adjustment resulting from adopting new financial instruments accounting standards |
| 4 |
| - |
|
Net income |
| 522 |
| 517 |
|
Common share dividends |
| (358) |
| (312) |
|
Balance at end of period |
| 2,892 |
| 2,474 |
|
|
|
|
|
|
|
Accumulated Other Comprehensive Loss, net of income taxes |
|
|
|
|
|
Balance at beginning of period |
| (90) |
| (90) |
|
Transition adjustment resulting from adopting new financial instruments accounting standards |
| (96) |
| - |
|
Other comprehensive loss |
| (183) |
| (6) |
|
Balance at end of period |
| (369) |
| (96) |
|
Total Shareholders’ Equity |
| 9,340 |
| 7,419 |
|
(1) Net of underwriting commissions and future income taxes.
See accompanying notes to the consolidated financial statements.
Accumulated Other Comprehensive Loss
(unaudited) |
| Currency Translation Adjustment |
| Cash Flow Hedges |
| Total |
|
Balance at December 31, 2006 |
| (90) |
| - |
| (90) |
|
Transition adjustment resulting from adopting new financial instruments standards |
| - |
| (96) |
| (96) |
|
Change in foreign currency translation gains and losses on investments in |
|
|
|
|
|
|
|
foreign operations (1) |
| (221) |
| - |
| (221) |
|
Change in gains and losses on hedge of investments in foreign operations (2) |
| 55 |
| - |
| 55 |
|
Change in gains and losses on derivative instruments designated as cash flow |
|
|
|
|
|
|
|
hedges (3) |
| - |
| (37) |
| (37) |
|
Reclassification to net income of gains and losses on derivative instruments |
|
|
|
|
|
|
|
designated as cash flow hedges pertaining to prior periods (4) (5) |
| - |
| 20 |
| 20 |
|
Balance at June 30, 2007 |
| (256) |
| (113) |
| (369) |
|
|
|
|
|
|
|
|
|
Balance at December 31, 2005 |
| (90) |
| - |
| (90) |
|
Change in foreign currency translation gains and losses on investments in |
|
|
|
|
|
|
|
foreign operations (1) |
| (30) |
| - |
| (30) |
|
Change in gains and losses on hedge of investments in foreign operations (2) |
| 24 |
| - |
| 24 |
|
Balance at June 30, 2006 |
| (96) |
| - |
| (96) |
|
(1) Net of tax expense of $56 million for the six months ended June 30, 2007 (2006 - $22 million expense).
(2) Net of tax expense of $28 million for the six months ended June 30, 2007 (2006 - $12 million expense).
(3) Net of tax recovery of $10 million for the six months ended June 30, 2007.
(4) Net of tax expense of $5 million for the six months ended June 30, 2007.
(5) During the next 12 months, the Company expects to reclassify to net income an estimated $128 million ($88 million after tax) of
net losses reported in accumulated other comprehensive income for cash flow hedges.
See accompanying notes to the consolidated financial statements.
Notes to Consolidated Financial Statements
(Unaudited)
1. Significant Accounting Policies
The consolidated financial statements of TransCanada Corporation (TransCanada or the Company) have been prepared in accordance with Canadian generally accepted accounting principles (GAAP). The accounting policies applied are consistent with those outlined in TransCanada’s annual audited consolidated financial statements for the year ended December 31, 2006, except for the changes noted below. These consolidated financial statements reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position and results of operations for the respective periods. These consolidated financial statements do not include all disclosures required in the annual financial statements and should be read in conjunction with the 2006 audited consolidated financial statements included in TransCanada’s 2006 Annual Report. Amounts are stated in Canadian dollars unless otherwise indicated. Certain comparative figures have been reclassified to conform with current period’s presentation.
In Pipelines, which consists primarily of the Company’s investments in regulated pipelines and natural gas storage facilities, annual revenues and net earnings fluctuate over the long term based on regulators’ decisions and negotiated settlements with shippers. Generally, quarter-over-quarter revenues and net earnings during any particular fiscal year remain relatively stable with fluctuations resulting from adjustments being recorded due to regulatory decisions and negotiated settlements with shippers, seasonal fluctuations in short-term throughput on U.S. pipelines and items outside of the normal course of operations.
In Energy, which consists primarily of the Company’s investments in electrical power generation plants and non-regulated natural gas storage facilities, quarter-over-quarter revenues and net earnings are affected by seasonal weather conditions, customer demand, market prices, planned and unplanned plant outages as well as items outside of the normal course of operations.
Since a determination of the value of many assets, liabilities, revenues and expenses is dependent upon future events, the preparation of these consolidated financial statements requires the use of estimates and assumptions. In the opinion of Management, these consolidated financial statements have been properly prepared within reasonable limits of materiality and within the framework of the Company’s significant accounting policies.
2. Changes In Accounting Policies
Changes for Second Quarter 2007
Proprietary Natural Gas Storage Inventories and Revenue Recognition
The new Canadian Institute of Chartered Accountants (CICA) Handbook accounting requirements for Section 3031 “Inventories” will become effective January 1, 2008. However, the Company has chosen to adopt this
standard as of April 2007. Adjustments to second quarter 2007 consolidated financial statements have been made in accordance with the transitional provisions for this new standard.
Beginning April 1, 2007, TransCanada’s proprietary natural gas storage inventory will be valued at its fair value, as measured by the one-month forward price for natural gas. In order to record inventory at fair value, TransCanada has designated its natural gas storage business as a “broker/trader business” that purchases and sells natural gas on a back-to-back basis. The Company did not have any proprietary natural gas inventory prior to April 1, 2007. The Company records its proprietary natural gas storage results in Revenues net of Commodity Purchases Resold.
At June 30, 2007, $81 million of proprietary natural gas storage inventory was included in Inventories on the Consolidated Balance Sheet. All changes in the fair value of the proprietary natural gas storage inventory will be recorded in Inventories and Revenues. During the three months ended June 30, 2007, unrealized pre-tax losses related to the change in fair value of the proprietary natural gas storage inventory were $23 million, which was essentially offset by the change in fair value of the forward proprietary natural gas storage purchase and sale contracts.
Changes for First Quarter 2007
Effective January 1, 2007, the Company adopted the new CICA Handbook accounting requirements for Section 1506 “Accounting Changes”, Section 1530 “Comprehensive Income”, Section 3251 “Equity”, Section 3855 “Financial Instruments – Recognition and Measurement”, Section 3861 “Financial Instruments – Disclosure and Presentation”, and Section 3865 “Hedges”. Adjustments to the consolidated financial statements for the first six months in 2007 have been made in accordance with the transitional provisions for these new standards.
Comprehensive Income and Equity
The Company’s financial statements include statements of Consolidated Comprehensive Loss and Accumulated Other Comprehensive Loss. In addition, as required by Section 3251, the Company now presents separately in its Consolidated Shareholders’ Equity the changes for each of its components of Shareholders’ Equity, including Accumulated Other Comprehensive Loss.
Financial Instruments
All financial instruments, including derivatives, are included on the balance sheet initially at fair value. The financial assets are classified as held for trading, held to maturity, loans and receivables, or available for sale. Financial liabilities are classified as held for trading or other financial liabilities. Subsequent measurement is determined by classification.
Held-for-trading financial assets and liabilities consist of swaps, options, forwards and futures and are entered into with the intention of generating a profit. These financial instruments are initially accounted for at their fair value and changes to fair value included in Revenues. Held-to-maturity financial assets are accounted for at their
amortized cost using the effective interest method. The Company did not have any of these financial instruments at June 30, 2007. Loans and receivables are accounted for at their amortized cost using the effective interest method. The available-for-sale classification includes non-derivative financial assets that are designated as available for sale or are not included in the other three classifications. These instruments are initially accounted for at their fair value and changes to fair value are recorded through Other Comprehensive Income. Income earned from these assets is included in Interest Income and Other.
Other financial liabilities not classified as held for trading are accounted for at their amortized cost, using the effective interest method. Interest expense is included in Financial Charges and Financial Charges of Joint Ventures.
Derivatives embedded in other financial instruments or contracts (the host instrument) are recorded as separate derivatives and are measured at fair value if the economic characteristics of the embedded derivative are not closely related to the host instrument, the terms of the embedded derivative are the same as those of a stand-alone derivative and the total contract is not held for trading or accounted for at fair value. Changes in fair value of the embedded derivative are included in Revenues. All derivatives, other than those that meet the normal purchases and sales exceptions or are not within the scope of Section 3855, are carried on the balance sheet at fair value. The Company used January 1, 2003 as the transition date for embedded derivatives.
Transaction costs are incremental costs that are directly attributable to the acquisition, issue or disposal of a financial instrument. Effective January 1, 2007, the Company began offsetting long-term debt transaction costs against the associated debt and began amortizing these costs using the effective interest method. Previously, these costs were amortized on a straight-line basis over the life of the debt. There was no material effect on the Company’s financial statements as a result of this change in policy. In second quarter and the first six months of 2007, the charge to Net Income for the amortization of transaction costs using the effective interest method was immaterial.
As part of the accounting for the Company’s regulated operations, gains or losses from the changes in the fair value of financial instruments within the regulated operations are included in regulatory assets or regulatory liabilities.
Hedges
Section 3865 specifies the circumstances under which hedge accounting is permissible, how hedge accounting may be performed and where the impacts should be recorded. The standard introduces three specific types of hedging relationships: fair value hedges, cash flow hedges and hedges of a net investment in self-sustaining foreign operations.
As part of its asset and liability management, the Company uses derivatives for hedging positions to reduce its exposure to credit and market risk. The Company designates certain derivatives as hedges and prepares documentation at the inception of the hedging contract. The Company performs an assessment at inception and during the term of the contract to determine if the derivative used as a hedge is effective in offsetting the risks in the values or cash flows of the hedged financial
instrument. All derivatives are initially recorded at fair value and adjusted to fair value at each reporting date.
Fair value hedges primarily consist of interest rate swaps used to mitigate the effect of changes in the fair value of fixed-rate long-term financial instruments due to movements in market interest rates. Changes in the value of fair value hedges and the corresponding underlying transactions are recorded in Financial Charges and Interest Income and Other, for hedges of interest rates and foreign exchange rates, respectively. Any gains or losses arising from ineffectiveness are recognized immediately in income in the same financial category as the underlying transaction.
The Company uses cash flow hedges for its anticipated transactions to reduce exposure to fluctuations in interest rates, foreign exchange rates and changes in commodity prices. The effective portion of changes in the value of cash flow hedges is recognized in Other Comprehensive Income. Ineffective portions and amounts excluded from effectiveness testing of hedges are included in income in the same financial category as the underlying transaction. Gains or losses from cash flow hedges that have been included in Accumulated Other Comprehensive Income are included in Net Income when the underlying transaction has occurred or becomes probable of not occurring. The maximum length of time the Company is hedging its exposure to variability in future cash flows is 10 years. The Company hedges its foreign currency exposure of investments in self-sustaining foreign operations with certain cross-currency swaps, forward exchange contracts and options. These financial instruments are adjusted to fair value and the effective portion of gains or losses associated with these adjustments are included in Other Comprehensive Income. In addition, the Company hedges its net investment with U.S. dollar-denominated debt, which is valued at period-end foreign exchange rates. Gains or losses arising from ineffective portions of the hedge are included in income. Gains or losses from these hedges that have been included in Accumulated Other Comprehensive Income are reclassified to Net Income in the event the Company settles or otherwise reduces its investment.
Net Effect of Accounting Policy Changes
The net effect to the Company’s financial statements at January 1, 2007 resulting from the above-mentioned changes in accounting policies is as follows.
Increases/(decreases) |
|
|
|
(unaudited) |
|
|
|
(millions of dollars) |
|
|
|
|
|
|
|
Other current assets |
| (127) |
|
Other assets |
| (203) |
|
Accounts payable |
| (29) |
|
Deferred amounts |
| (75) |
|
Future income taxes |
| (42) |
|
Long-term debt |
| (85) |
|
Long-term debt of joint ventures |
| (7) |
|
Accumulated other comprehensive loss |
| (186) |
|
Foreign exchange adjustment |
| 90 |
|
Retained earnings |
| 4 |
|
Future Accounting Changes
Section 1535 Capital Disclosures
Effective for interim and annual financial statements for fiscal years beginning on or after October 1, 2007, the new CICA Handbook Section 1535 “Capital Disclosures” requires the disclosure of qualitative and quantitative information about the Company’s objectives, policies and processes for managing capital.
Section 3862 Financial Instruments – Disclosures and Section 3863 – Financial Instruments – Presentation
Effective for interim and annual financial statements for fiscal years beginning on or after October 1, 2007, the new CICA Handbook Sections 3862 and 3863 will replace Section 3861 to prescribe the requirements for presentation and disclosure of financial instruments.
3. Segmented Information
Three months ended June 30 |
| Pipelines |
|
| Energy |
| Corporate |
| Total |
| ||||||||||||||
(unaudited - millions of dollars) |
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
Revenues |
| 1,228 |
|
| 969 |
|
| 984 |
|
| 716 |
|
| - |
|
| - |
|
| 2,212 |
|
| 1,685 |
|
Plant operating costs and other |
| (417 | ) |
| (326 | ) |
| (343 | ) |
| (236 | ) |
| (1 | ) |
| (4 | ) |
| (761 | ) |
| (566 | ) |
Commodity purchases resold |
| (65 | ) |
| - |
|
| (462 | ) |
| (337 | ) |
| - |
|
| - |
|
| (527 | ) |
| (337 | ) |
Depreciation |
| (260 | ) |
| (235 | ) |
| (40 | ) |
| (31 | ) |
| - |
|
| - |
|
| (300 | ) |
| (266 | ) |
|
| 486 |
|
| 408 |
|
| 139 |
|
| 112 |
|
| (1 | ) |
| (4 | ) |
| 624 |
|
| 516 |
|
Financial charges and non-controlling interests |
| (206 | ) |
| (184 | ) |
| - |
|
| - |
|
| (78 | ) |
| (34 | ) |
| (284 | ) |
| (218 | ) |
Financial charges of joint ventures |
| (13 | ) |
| (19 | ) |
| (6 | ) |
| (5 | ) |
| - |
|
| - |
|
| (19 | ) |
| (24 | ) |
Income from equity investments |
| 5 |
|
| 6 |
|
| - |
|
| - |
|
| - |
|
| - |
|
| 5 |
|
| 6 |
|
Interest income and other |
| 11 |
|
| 2 |
|
| 3 |
|
| 1 |
|
| 29 |
|
| 12 |
|
| 43 |
|
| 15 |
|
Gain on sale of Northern Border Partners, L.P. interest |
| - |
|
| 23 |
|
| - |
|
| - |
|
| - |
|
| - |
|
| - |
|
| 23 |
|
Income taxes |
| (117 | ) |
| (89 | ) |
| (42 | ) |
| (11 | ) |
| 47 |
|
| 26 |
|
| (112 | ) |
| (74 | ) |
Income from Continuing Operations |
| 166 |
|
| 147 |
|
| 94 |
|
| 97 |
|
| (3 | ) |
| - |
|
| 257 |
|
| 244 |
|
Income from Discontinued Operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| - |
|
| - |
|
Net Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 257 |
|
| 244 |
|
Six months ended June 30 |
| Pipelines |
|
| Energy |
|
| Corporate |
|
| Total |
| ||||||||||||
(unaudited - millions of dollars) |
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
Revenues |
| 2,352 |
|
| 1,946 |
|
| 2,109 |
|
| 1,633 |
|
| - |
|
| - |
|
| 4,461 |
|
| 3,579 |
|
Plant operating costs and other |
| (800 | ) |
| (643 | ) |
| (690 | ) |
| (455 | ) |
| (3 | ) |
| (5 | ) |
| (1,493 | ) |
| (1,103 | ) |
Commodity purchases resold |
| (65 | ) |
| - |
|
| (1,038 | ) |
| (842 | ) |
| - |
|
| - |
|
| (1,103 | ) |
| (842 | ) |
Depreciation |
| (511 | ) |
| (461 | ) |
| (79 | ) |
| (62 | ) |
| - |
|
| - |
|
| (590 | ) |
| (523 | ) |
|
| 976 |
|
| 842 |
|
| 302 |
|
| 274 |
|
| (3 | ) |
| (5 | ) |
| 1,275 |
|
| 1,111 |
|
Financial charges and non-controlling interests |
| (423 | ) |
| (376 | ) |
| 1 |
|
| - |
|
| (127 | ) |
| (69 | ) |
| (549 | ) |
| (445 | ) |
Financial charges of joint ventures |
| (29 | ) |
| (33 | ) |
| (11 | ) |
| (12 | ) |
| - |
|
| - |
|
| (40 | ) |
| (45 | ) |
Income from equity investments |
| 11 |
|
| 24 |
|
| - |
|
| - |
|
| - |
|
| - |
|
| 11 |
|
| 24 |
|
Interest income and other |
| 18 |
|
| 34 |
|
| 6 |
|
| 3 |
|
| 44 |
|
| 27 |
|
| 68 |
|
| 64 |
|
Gain on sale of Northern Border Partners, L.P. interest |
| - |
|
| 23 |
|
| - |
|
| - |
|
| - |
|
| - |
|
| - |
|
| 23 |
|
Income taxes |
| (232 | ) |
| (210 | ) |
| (98 | ) |
| (68 | ) |
| 87 |
|
| 35 |
|
| (243 | ) |
| (243 | ) |
Income from Continuing Operations |
| 321 |
|
| 304 |
|
| 200 |
|
| 197 |
|
| 1 |
|
| (12 | ) |
| 522 |
|
| 489 |
|
Income from Discontinued Operations |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| - |
|
| 28 |
|
Net Income |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| 522 |
|
| 517 |
|
Total Assets |
|
|
|
|
| |
(unaudited - millions of dollars) |
| June 30, 2007 |
|
| December 31, 2006 |
|
Pipelines |
| 22,753 |
|
| 18,320 |
|
Energy |
| 6,509 |
|
| 6,500 |
|
Corporate |
| 1,060 |
|
| 1,089 |
|
|
| 30,322 |
|
| 25,909 |
|
4. Acquisitions and Dispositions
ANR and Great Lakes
In February 2007, TransCanada acquired American Natural Resources Company and ANR Storage Company (together ANR) and an additional 3.55 per cent interest in Great Lakes from El Paso Corporation for approximately US$3.4 billion, subject to certain post-closing adjustments, including US$491 million of assumed long-term debt. The
acquisition was accounted for using the purchase method of accounting. TransCanada began consolidating ANR and Great Lakes in the Pipelines segment subsequent to the acquisition date. The preliminary allocation of the purchase price was as follows.
Purchase Price Allocation |
|
|
|
|
|
|
| ||
(unaudited) |
|
|
|
|
|
|
| ||
(millions of US dollars) |
| ANR |
|
| Great Lakes |
|
| Total |
|
Current assets |
| 258 |
|
| 4 |
|
| 262 |
|
Plant, property and equipment |
| 1,874 |
|
| 35 |
|
| 1,909 |
|
Other non-current assets |
| 82 |
|
| - |
|
| 82 |
|
Goodwill |
| 1,767 |
|
| 37 |
|
| 1,804 |
|
Current liabilities |
| (177 | ) |
| (3 | ) |
| (180) |
|
Long-term debt |
| (475 | ) |
| (16 | ) |
| (491) |
|
Other non-current liabilities |
| (447 | ) |
| (22 | ) |
| (469) |
|
|
| 2,882 |
|
| 35 |
|
| 2,917 |
|
A preliminary allocation of the purchase price has been made using fair values of the net assets at the date of acquisition. As ANR’s and Great Lakes’ tolls are subject to rate regulation based on historical costs, the regulated net assets, other than gas held for sale, were determined to have a fair value equal to their rate- regulated values.
Goodwill will be evaluated on an annual basis for impairment. Factors that contributed to goodwill included the opportunity to expand in the U.S. market and gaining a stronger competitive position in the North American gas transmission business. The goodwill recognized on this transaction is not amortizable for tax purposes.
PipeLines LP Acquisition of Great Lakes
In February 2007, PipeLines LP acquired a 46.45 per cent interest in Great Lakes from El Paso Corporation for approximately US$945 million, subject to certain post-closing adjustments, including US$209 million of assumed long-term debt. The acquisition was accounted for using the purchase method of accounting. TransCanada began consolidating Great Lakes in the Pipelines segment subsequent to the acquisition date. The preliminary allocation of the purchase price was as follows.
Purchase Price Allocation |
|
|
|
(unaudited) |
|
|
|
(millions of US dollars) |
|
|
|
Current assets |
| 42 |
|
Plant, property and equipment |
| 465 |
|
Other non-current assets |
| 1 |
|
Goodwill |
| 460 |
|
Current liabilities |
| (23 | ) |
Long-term debt |
| (209 | ) |
|
| 736 |
|
A preliminary allocation of the purchase price has been made using fair values of the net assets at the date of acquisition. As Great Lakes’ tolls are subject to rate regulation based on historical costs, the regulated net assets were determined to have a fair value equal to their rate-regulated values.
Goodwill will be evaluated on an annual basis for impairment. Factors that contributed to goodwill included the opportunity to expand in the U.S. market and gaining a stronger competitive position in the North American gas transmission business. The goodwill recognized on this transaction is amortizable for tax purposes.
PipeLines LP
In February 2007, PipeLines LP completed a private placement offering of 17,356,086 common units at a price of US$34.57 per unit, of which 50 per cent of the units were acquired by TransCanada for US$300 million. TransCanada also invested an additional US$12 million to maintain its general partnership ownership interest in PipeLines LP. As a result of these additional investments in PipeLines LP, TransCanada’s ownership in PipeLines LP increased to 32.1 per cent on February 22, 2007. The total private placement plus TransCanada’s additional investment resulted in gross proceeds to PipeLines LP of US$612 million, which were used to partially finance its Great Lakes acquisition.
5. Notes Payable and Long-Term Debt
In April 2007, TransCanada issued US$1.0 billion of Junior Subordinated Notes (“Notes”) maturing in 2067 and bearing interest of 6.35 per cent until May 15, 2017 at which time the interest on the Notes will convert to a floating rate, reset quarterly to the three-month London Interbank Offered Rate (LIBOR) plus 221 basis points. The Notes’ effective interest rate at June 30, 2007 was 6.51 per cent. TransCanada has the option to defer payment of interest for one or more periods of up to ten years without giving rise to an event of default and without permitting acceleration of payment under the terms of the Notes. If this were to occur, the Company would be prohibited from paying dividends during the deferral period. The Notes are subordinated in right of payment to existing and future senior indebtedness and are effectively subordinated to all indebtedness and obligations of TCPL. The Notes are callable at TransCanada’s option at any time on or after May 15, 2017 at 100 per cent of the principal amount of the Notes plus accrued and unpaid interest to the date of redemption. Upon the occurrence of certain events, the Notes are callable earlier at TransCanada’s option, in whole or in part, at an amount equal to the greater of 100 per cent of the principal amount of the Notes plus accrued and unpaid interest to the date of redemption or at an amount determined by formula in accordance with the terms of the Notes.
In April 2007, Northern Border established a US$250 million five-year bank facility. A portion of the bank facility was drawn to refinance US$150-million of senior notes that matured on May 1, 2007, with the balance available to fund Northern Border’s ongoing operations.
In March 2007, the Company filed debt shelf prospectuses in Canada and the U.S. qualifying for issuance of $1.5 billion of medium-term notes and US$1.5 billion of debt securities, respectively. At June 30, 2007, the Company had issued no medium-term notes and US$1.0 billion of debt securities under these prospectuses.
In March 2007, ANR Pipeline Company voluntarily withdrew from the New York Stock Exchange the listing of its 9.625 per cent Debentures due 2021,
7.375 per cent Debentures due 2024, and 7.0 per cent Debentures due 2025. With the delisting, which became effective April 12, 2007, ANR Pipeline Company deregistered these securities from registration with the U.S. Securities Exchange Commission (SEC).
In February 2007, the Company executed an agreement for a US$2.2 billion, committed, unsecured, one-year bridge loan facility with a floating interest rate based on the one-month LIBOR plus 25 basis points. The Company utilized $1.5 billion and US$700 million from this facility to partially finance the ANR and Great Lakes acquisition. At June 30, 2007, the Company had an outstanding balance of US$488 million on this facility. The undrawn balance of this facility has been cancelled and is no longer available to the Company.
In February 2007, the Company established a US$1.0-billion committed, unsecured credit facility, consisting of a US$700-million five-year term loan and a US$300-million five-year, extendible revolving facility. A floating interest rate based on the three-month LIBOR plus 22.5 basis points is charged on the balance outstanding and a facility fee of 7.5 basis points is charged on the entire facility. The Company utilized US$1.0 billion from this facility and an additional US$100 million from an existing demand line to partially finance the ANR acquisition as well as its additional investment in PipeLines LP. At June 30, 2007, the Company had an outstanding balance of US$700 million on the credit facility and had repaid the demand line.
In February 2007, PipeLines LP increased the size of its syndicated revolving credit and term loan facility in connection with its Great Lakes acquisition. The amount available under the facility increased from US$410 million to US$950 million, consisting of a US$700-million senior term loan and a US$250-million senior revolving credit facility, with US$194 million of the senior term loan amount available being terminated upon closing of the Great Lakes acquisition. At June 30, 2007, US$506 million of the senior term loan and US$10 million of the senior revolving credit facility remained outstanding. A floating interest rate based on the three-month LIBOR plus 55 basis points is charged on the senior term loan and a floating interest rate based on the one-month LIBOR plus 35 basis points is charged on the senior revolving credit facility. A facility fee of 10 basis points is charged on the US$250 million senior revolving credit facility. The weighted average interest rate at June 30, 2007 was 5.94 per cent.
6. Preferred Securities
On July 5, 2007, TransCanada redeemed, at par, all of the outstanding US$460 million 8.25 per cent Preferred Securities due 2047. The redemption occurred as a result of a five-year tolls settlement reached on the Canadian Mainline. The redemption crystallized a foreign exchange gain that will flow through to the Canadian Mainline’s customers.
7. Share Capital
In second quarter 2007, TransCanada issued 1.3 million common shares under its Dividend Reinvestment Program, resulting in proceeds of approximately $51 million.
In February and March 2007, TransCanada issued, through a subscription receipts offering, 45,390,500 common shares at a price of $38.00 each, resulting in gross proceeds of approximately $1.725 billion, which were used towards financing the acquisition of ANR and Great Lakes.
In January 2007, TransCanada filed a short form shelf prospectus with securities regulators in Canada and the U.S. to allow for the offering of up to $3.0 billion of common shares, preferred shares and/or subscription receipts in Canada and the U.S. until February 2009. As at June 30, 2007, the Company had issued $1.725 billion in common shares under this shelf prospectus, which were used towards financing the acquisition of ANR.
8. Financial Instruments and Risk Management
The fair values of non-derivative financial instruments at June 30, 2007 are as follows.
Non-Derivative Financial Instruments Summary (1)
(unaudited) |
|
|
|
|
|
| |
(millions of dollars) |
| June 30, 2007 |
|
|
|
| |
|
| Fair |
|
|
|
| |
|
| Value |
|
|
|
|
|
Financial Assets(2) (3) |
|
|
|
|
|
|
|
Cash and cash equivalents (4) |
| 340 |
|
|
|
|
|
Loans and receivables (4) |
| 1,142 |
|
|
|
|
|
Available-for-sale assets |
| 13 |
|
|
|
|
|
|
| 1,495 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Financial Liabilities (3) (5) (6) |
|
|
|
|
|
|
|
Notes payable |
| 728 |
|
|
|
|
|
Trade and other payables |
| 1,187 |
|
|
|
|
|
Long-term debt |
| 14,520 |
|
|
|
|
|
Preferred securities |
| 489 |
|
|
|
|
|
Other long-term liabilities |
| 65 |
|
|
|
|
|
|
| 16,989 |
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) | Consolidated Net Income for the three months and six months ended June 30, 2007 included a $2 million unrealized loss for the fair value adjustments to these financial instruments. |
(2) | At June 30, 2007, Current Assets on the Consolidated Balance Sheet included financial assets of $932 million in Accounts Receivable and $340 million in Cash and Cash Equivalents. The remainder of these financial assets were included in Other Assets. |
(3) | Carrying value is not materially different from fair value, except for available-for-sale financial assets, which have a carrying value equal to fair value. |
(4) | Recorded at cost. |
(5) | Recorded at amortized cost. |
(6) | At June 30, 2007, Current Liabilities on the Consolidated Balance Sheet included financial liabilities of $1,178 million in Accounts Payable and $728 million in Notes Payable. Financial liabilities of $74 million were included in Deferred Amounts, $14,520 million were included in Long-Term Debt and $489 million were included in Preferred Securities. |
The fair values of the Company’s derivative financial instruments are as follows.
Derivative Financial Instruments Summary (1)
(unaudited) |
|
|
|
|
|
| |
(millions of dollars) |
| June 30, 2007 |
|
|
|
| |
|
| Fair |
|
|
|
|
|
|
| Value |
|
|
|
|
|
Derivative financial instruments held for trading |
|
|
|
|
|
|
|
Power derivatives-assets (2) |
| 38 |
|
|
|
|
|
Power derivatives-liabilities (2) |
| (31 | ) |
|
|
|
|
Natural gas derivatives-assets (3) |
| 67 |
|
|
|
|
|
Natural gas derivatives-liabilities (3) |
| (34 | ) |
|
|
|
|
Interest rate derivatives-assets (4) |
| 18 |
|
|
|
|
|
Interest rate derivatives-liabilities (4) |
| (4 | ) |
|
|
|
|
Foreign exchange derivatives-assets (4) |
| 3 |
|
|
|
|
|
Foreign exchange derivatives-liabilities (4) |
| (67 | ) |
|
|
|
|
|
| (10 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
Derivative financial instruments in hedging relationships (5) |
|
|
|
|
|
|
|
Power derivatives-assets (6) |
| 102 |
|
|
|
|
|
Power derivatives-liabilities (6) |
| (269 | ) |
|
|
|
|
Natural gas derivatives-assets (6) |
| 30 |
|
|
|
|
|
Natural gas derivatives-liabilities (6) |
| (9 | ) |
|
|
|
|
Interest rate derivatives-assets (7) |
| 9 |
|
|
|
|
|
Interest rate derivatives-liabilities (7) |
| (5 | ) |
|
|
|
|
Foreign exchange derivatives-assets (7) |
| - |
|
|
|
|
|
Foreign exchange derivatives-liabilities (7) |
| (54 | ) |
|
|
|
|
|
| (196 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
Total Derivative Financial Instruments |
| (206 | ) |
|
|
|
|
|
|
|
|
|
|
|
|
(1) | Fair value is equal to the carrying value of these derivatives except for derivatives used in the Company’s regulatory operations which are carried at their regulatory values. |
(2) | Consolidated Net Income for the three and six months ended June 30, 2007 included a $15 million unrealized loss and a $4 million unrealized gain, respectively, for the change in the fair value of held-for-trading power derivatives. |
(3) | Consolidated Net Income for the three and six months ended June 30, 2007 included $4 million and $10 million, respectively, of unrealized gains for the change in the fair value of held-for-trading natural gas derivatives. |
(4) | Consolidated Net Income for the three and six months ended June 30, 2007 included a $6 million unrealized loss and a $1 million unrealized gain, respectively, for the change in the fair value of held-for-trading interest-rate and foreign exchange derivatives. |
(5) | All hedging relationships are designated cash flow hedges except for $4 million of interest-rate derivative financial instruments designated as fair value hedges. |
(6) | Consolidated Net Income for the three and six months ended June 30, 2007 included nil and a $6 million gain, respectively, for the changes in fair value of power and natural gas cash flow hedges that were ineffective in offsetting the change in fair value of their related underlyings. |
(7) | Consolidated Net Income for the three and six months ended June 30, 2007 included a $4 million loss for the change in fair value of interest-rate and foreign exchange cash flow hedges and fair value hedges that were ineffective in offsetting the change in fair value of their related underlyings. |
Unrealized Gains and Losses
At June 30, 2007, there were unrealized gains from unsettled derivative financial instruments of $147 million (December 31, 2006 - $41 million) included in Other Current Assets and $120 million (December 31, 2006 - $39 million) included in Other Assets. At June 30, 2007, there were unrealized losses from unsettled derivative financial instruments of $220 million (December 31, 2006 - $144 million) included in Accounts Payable and $253 million (December 31, 2006 - $158 million) included in Deferred Amounts. At June 30, 2007, there were unrealized losses from the fair value adjustments of proprietary natural gas storage inventory of $23 million (December 31, 2006 - nil) included in Inventories.
Energy Price, Interest Rate and Foreign Exchange Rate Risk Management
The Company enters into various contracts to mitigate its exposure to fluctuations in interest rates, foreign exchange rates and commodity prices. The contracts generally consist of the following.
• Forwards and futures contracts - contractual agreements to buy or sell a specific financial instrument or commodity at a specified price and date in the future. The Company enters into foreign exchange and commodity forwards and futures to mitigate volatility in changes in foreign exchange rates and power and gas prices, respectively.
• Swaps - contractual agreements between two parties to exchange streams of payments over time according to specified terms. The Company enters into interest rate, cross-currency and commodity swaps to mitigate changes in interest rates, foreign exchange rates and commodity prices, respectively.
• Options - contractual agreements to convey the right, but not the obligation, for the purchaser either to buy or sell a specific amount of a financial instrument or commodity at a fixed price, either at a fixed date or at any time within a specified period. The Company enters into option agreements to mitigate changes in interest rates, foreign exchange rates and commodity prices.
• Heat rate contracts - contracts for the sale or purchase of power that are priced based on a natural gas index.
Energy Price Risk
The Company is exposed to energy price movements as part of its normal business operations, particularly in relation to the prices of electricity and natural gas. The primary risk is that market prices for commodities will move adversely between the time that purchase and/or sales prices are fixed, potentially reducing expected margins.
To manage exposure to price risk, subject to the Company’s overall risk management policies and procedures, the Company commits a significant portion of its supply to medium- to long-term sales contracts while reserving an amount of unsold supply to maintain flexibility in the overall management of its asset portfolio. The types of instruments used include forwards and futures contracts, swaps, options, and heat rate contracts.
TransCanada manages its exposure to seasonal gas price spreads in its natural gas storage business, by hedging storage capacity with a portfolio of third party storage capacity leases and back-to-back proprietary natural gas purchases and sales. By matching purchases and sales volumes, TransCanada locks in a margin and effectively eliminates its exposure to the price movements of natural gas.
The Company continually assesses its power contracts and derivative instruments used to manage energy price risk. Contracts, with the exception of leases, have been assessed to determine whether they meet the definition of a derivative. Certain commodity purchase and sale contracts are derivatives but are not within the scope of CICA Handbook Section 3855, as they were entered into and continue to be held for the purpose of receipt or delivery in accordance with the Company’s expected purchase, sale or usage requirements (“normal purchases and sales exception”), are considered to be executory contracts or meet other exemption criteria listed in Section 3855.
Interest Rate Risk
The Company has fixed interest rate long-term debt, which subjects the Company to interest rate price risk, and has floating interest rate long-term debt, which subjects the Company to interest rate cash flow risk. To manage its exposure to these risks, the Company uses a combination of interest-rate swaps, forwards and options.
Investments in Foreign Operations
The Company hedges its net investment in self-sustaining foreign operations with U.S. dollar-denominated debt, cross-currency swaps, forward exchange contracts and options. At June 30, 2007, the Company had designated U.S. dollar-denominated debt with a carrying value of $4,104 million (US$3,859 million) and a fair value of $4,178 million (US$3,929 million) as a portion of this hedge and swaps, forwards and options with a fair value of $75 million (US$70 million) as net investment hedges.
Net Investment in Foreign Operations |
|
|
|
|
|
|
|
|
|
|
Asset/(Liability) |
|
|
|
|
|
|
|
|
|
|
(millions of dollars) |
| June 30, 2007 |
|
| December 31, 2006 |
| ||||
|
|
|
| Notional or |
|
|
|
| Notional or |
|
|
| Fair |
| Principal |
|
| Fair |
| Principal |
|
|
| Value(1) |
| Amount |
|
| Value(1) |
| Amount |
|
Derivative financial Instruments in hedging relationships |
|
|
|
|
|
|
|
|
|
|
U.S. dollar cross-currency swaps |
| 75 |
| U.S. 350 |
|
| 58 |
| U.S. 400 |
|
U.S. dollar forward foreign exchange contracts |
| - |
| U.S. 75 |
|
| (7 | ) | U.S. 390 |
|
U.S. dollar options |
| - |
| U.S. 50 |
|
| (6 | ) | U.S. 500 |
|
|
|
|
|
|
|
|
|
|
|
|
|
| 75 |
| U.S. 475 |
|
| 45 |
| U.S. 1,290 |
|
(1) Fair values are equal to carrying values.
Fair Values
Fair values of financial instruments are determined by reference to quoted bid or asking price, as appropriate, in active markets. In the absence of an active market, the Company determines fair value by using valuation techniques that refer to observable market data or estimated market prices. These include comparisons with similar instruments where market observable prices exist, option pricing models and other valuation techniques commonly used by market participants. Fair values determined using valuation models require the use of assumptions concerning the amount and timing of estimated future cash flows and discount rates. In determining those assumptions, the Company looks primarily to external readily observable market input factors such as interest rate yield curves, currency rates, and price and rate volatilities as applicable.
9. Income Taxes
In second quarter 2007, TransCanada recorded income tax benefits of approximately $16 million as a result of changes in Canadian federal income tax legislation.
In first quarter 2007, TransCanada recorded income tax benefits of approximately $10 million from the resolution of certain income tax matters, as well as a $5 million income tax benefit from an internal restructuring.
10. Employee Future Benefits
The net benefit plan expense for the Company’s defined benefit pension plans and other post-employment benefit plans for the three and six months ended June 30, 2007 is as follows.
Three months ended June 30 |
| Pension Benefit Plans |
|
| Other Benefit Plans |
|
| ||||||
(unaudited - millions of dollars) |
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
|
Current service cost |
| 11 |
|
| 9 |
|
| 1 |
|
| 1 |
|
|
Interest cost |
| 18 |
|
| 16 |
|
| 2 |
|
| 2 |
|
|
Expected return on plan assets |
| (20 | ) |
| (17 | ) |
| (1 | ) |
| (1 | ) |
|
Amortization of net actuarial loss |
| 6 |
|
| 7 |
|
| - |
|
| - |
|
|
Amortization of past service costs |
| 1 |
|
| 1 |
|
| (1 | ) |
| 1 |
|
|
Net benefit cost recognized |
| 16 |
|
| 16 |
|
| 1 |
|
| 3 |
|
|
Six months ended June 30 |
| Pension Benefit Plans |
|
| Other Benefit Plans |
|
| ||||||
(unaudited - millions of dollars) |
| 2007 |
|
| 2006 |
|
| 2007 |
|
| 2006 |
|
|
Current service cost |
| 22 |
|
| 18 |
|
| 1 |
|
| 1 |
|
|
Interest cost |
| 35 |
|
| 33 |
|
| 3 |
|
| 4 |
|
|
Expected return on plan assets |
| (39 | ) |
| (35 | ) |
| (1 | ) |
| (1 | ) |
|
Amortization of transitional obligation related to |
|
|
|
|
|
|
|
|
|
|
|
|
|
regulated business |
| - |
|
| - |
|
| 1 |
|
| 1 |
|
|
Amortization of net actuarial loss |
| 12 |
|
| 14 |
|
| 1 |
|
| 1 |
|
|
Amortization of past service costs |
| 2 |
|
| 2 |
|
| (1 | ) |
| 1 |
|
|
Net benefit cost recognized |
| 32 |
|
| 32 |
|
| 4 |
|
| 7 |
|
|
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: Shela Shapiro at (403) 920-7859 |
|
Visit TransCanada’s Internet site at: http://www.transcanada.com |