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Derivative Instruments (Tables)
 12 Months Ended
Dec. 31, 2017
Derivative Instruments [Abstract]  
Schedule of Derivative Instruments [Table Text Block]
Derivative assets and liabilities relating to the foregoing categories consisted of the following:
Derivative AssetsDerivative Liabilities
As atDecember 31December 31December 31December 31
millions of Canadian dollars2017201620172016
Cash flow hedges
Power swaps$ 5$ 10$ 2$ 5
Foreign exchange forwards 2 - 5 22
7 10 7 27
Regulatory deferral
Commodity swaps and forwards
Coal purchases 137 83 10 9
Power purchases 5 7 3 4
Natural gas purchases and sales 6 33 7 2
Heavy fuel oil purchases 15 10 4 7
Foreign exchange forwards 32 106 4 -
195 239 28 22
HFT derivatives
Power swaps and physical contracts 125 47 162 71
Natural gas swaps, futures, forwards, physical contracts 105 111 294 484
230 158 456 555
Other derivatives
Interest rate swap 2 - - 1
Foreign exchange forwards - - - 1
2 - - 2
Total gross current derivatives 434 407 491 606
Impact of master netting agreements with intent to settle net or simultaneously (181) (131) (181) (131)
253 276 310 475
Current 141 145 227 325
Long-term 112 131 83 150
Total derivatives$ 253$ 276$ 310$ 475
Derivative assets and liabilities are classified as current or long-term based upon the maturities of the underlying contracts.
Offsetting Liabilities [Table Text Block]
Details of master netting agreements, shown net on the Consolidated Balance Sheets, are summarized in the following table:
Derivative AssetsDerivative Liabilities
As atDecember 31December 31December 31December 31
millions of Canadian dollars2017201620172016
Regulatory deferral$ 14$ 10$ 14$ 10
HFT derivatives 167 121 167 121
Total impact of master netting agreements withintent to settle net or simultaneously$ 181$ 131$ 181$ 131
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) [Table Text Block]
For theYear ended December 31
millions of Canadian dollars20172016
InterestForeignInterestForeign
PowerrateexchangePowerrateexchange
swapsswapsforwardsswapsswapsforwards
Realized gain (loss) in non-regulated fuel for generation and purchased power 3 - - 2 - -
Realized gain (loss) in operating revenue – Regulated - - (10) - - (12)
Realized gain (loss) in income from equity investments - - - - (1) -
Total gains (losses) in Net income$ 3$ - $ (10)$ 2$ (1)$ (12)
As at December 31
millions of Canadian dollars20172016
InterestForeignInterestForeign
PowerrateexchangePowerrateexchange
swapsswapsforwardsswapsswapsforwards
Total unrealized gain (loss) in AOCI – effective portion, net of tax$ - $ - $ (3)$ 2$ - $ (22)
The Company expects $5 million of unrealized losses currently in AOCI to be reclassified into net income within the next twelve months, as the underlying hedged transactions settle.

As at December 31, 2017, the Company had the following notional volumes of outstanding derivatives designated as cash flow hedges that are expected to settle as outlined below:
millions20182019202020212022
Foreign exchange forwards (USD) sales$ 45$ 30$ 30$ - $ -
Schedule Of Regulatory Deferred Gain Losses Derivatives [Table Text Block]
For theYear ended December 31
millions of Canadian dollars20172016
Commodity swaps and forwardsPhysical natural gas purchases and salesForeign exchange forwardsCommodity swaps and forwardsPhysical natural gas purchases and salesForeign exchange forwards
Unrealized gain (loss) in regulatory assets$ (33)$ (1)$ (4)$ 40$ - $ (2)
Unrealized gain (loss) in regulatory liabilities 83 1 (30) 101 (1) (30)
Realized (gain) loss in regulatory assets - - - - - 12
Realized (gain) loss in regulatory liabilities (2) - - - - (8)
Realized (gain) loss in inventory (1) (17) - (30) 5 - (44)
Realized (gain) loss in regulated fuel for generation and purchased power (2) (3) - (14) 17 (1) (18)
Total change derivative instruments$ 28$ - $ (78)$ 163$ (2)$ (90)
(1) Realized (gains) losses will be recognized in fuel for generation and purchased power when the hedged item is consumed.
(2) Realized (gains) losses on derivative instruments settled and consumed in the period; hedging relationships that have been terminated or the hedged transaction is no longer probable.
Schedule Of Regulatory Commody Swaps Forwards [Table Text Block]
20182019-2021
millions PurchasesPurchases
Coal (metric tonnes) 1 1
Natural Gas (Mmbtu) 30 14
Heavy fuel oil (bbls) - 1

20182019-2020
Foreign exchange contracts (millions of US dollars)$ 144$ 156
Weighted average rate 1.1061 1.2001
% of USD requirements79%40%
The Company reassesses foreign exchange forecasted periodically and will enter into additional hedges or unwind existing hedges, as required.
Unrealized Gain (Loss) on Investments [Table Text Block]
For the Year ended December 31
millions of Canadian dollars20172016
Power swaps and physical contracts in non-regulated operating revenues$ 7$ (1)
Natural gas swaps, forwards, futures and physical contracts in non-regulated operating revenues 401 69
Natural gas swaps, forwards, futures and physical contracts in non-regulated fuel for generation and purchased power 10 (7)
Power swaps, forwards, futures and physical contracts in non-regulated fuel for generation and purchased power 2 -
Foreign exchange options in other income (expenses), net - (2)
$ 420$ 59
Offsetting Liabilities Expected To Settle [Table Text Block]
millions 20182019202020212022
Natural gas purchases (Mmbtu) 325 134 62 44 41
Natural gas sales (Mmbtu) 250 56 21 8 2
Power purchases (MWh) 7 2 - - -
Power sales (MWh) 8 1 - - -
Foreign exchange options (USD)$ 2$ 4$ - $ - $ -
Derivative Documentation Unmet [Table Text Block]
Other Derivatives
The Company has recognized the following realized and unrealized gains (losses) with respect to cash flow hedges which documentation requirements have not been met:
For theYear ended December 31
millions of Canadian dollars20172016
InterestForeign InterestForeign
rateexchangerateexchange
swapsforwardsswapsforwards
Realized gain (loss) in other income (expense)$ - $ - $ - $ (87)
Unrealized gain (loss) in interest expense, net 2 - 2 -
Total gains (losses) in net income$ 2$ - $ 2$ (87)
As at December 31, 2017, the Company had interest rate swaps in place for the $250 million non-revolving term credit facility in Brunswick Pipeline for interest payments until the debt matures in 2019.
Schedules of Concentration of Risk, by Risk Factor [Table Text Block]
Concentration Risk
The Company's concentrations of risk consisted of the following:
As atDecember 31, 2017December 31, 2016
millions of Canadian dollars% of total exposuremillions of Canadian dollars% of total exposure
Receivables, net
Regulated utilities
Residential$ 32623%$ 31524%
Commercial 16111% 17013%
Industrial 463% 383%
Other 967% 695%
62944% 59245%
Trading group
Credit rating of A- or above 554% 524%
Credit rating of BBB- to BBB+ 614% 605%
Not rated 967% 574%
21215% 16913%
Other accounts receivable 30022% 25320%
1,14181% 1,01478%
Derivative Instruments (current and long-term)
Credit rating of A- or above 20715% 25220%
Credit rating of BBB- to BBB+ 101% 10%
Not rated 363% 232%
25319% 27622%
$ 1,394100%$ 1,290100%
Schedule of Financial Instruments Owned and Pledged as Collateral [Table Text Block]
As atDecember 31December 31
millions of Canadian dollars20172016
Cash collateral provided to others$ 119$ 91
Cash collateral received from others 99 52