XML 48 R20.htm IDEA: XBRL DOCUMENT
v3.10.0.1

Financial Instruments | 12 Months Ended
--- | ---
Dec. 31, 2018
Disclosure of detailed information about financial instruments [abstract] |
Financial Instruments | Financial Instruments A. Financial Assets and Liabilities – Classification and Measurement Financial assets and financial liabilities are measured on an ongoing basis at cost, fair value or amortized cost (see Note 2(C)). The following table outlines the carrying amounts and classifications of the financial assets and liabilities:
Carrying value as at Dec. 31, 2018 |  |  |  |  |
| Derivatives used for hedging |  | Derivatives held for trading (FVTPL) |  | Amortized cost |  | Other financial assets (FVTPL) |  | Total |
Financial assets |  |  |  |  |  |  |  |  |
Cash and cash equivalents(1) | — |  | — |  | 89 |  | — |  | 89 |
Restricted cash | — |  | — |  | 66 |  | — |  | 66 |
Trade and other receivables | — |  | — |  | 731 |  | 25 |  | 756 |
Long-term portion of finance lease receivables | — |  | — |  | 191 |  | — |  | 191 |
Risk management assets |  |  |  |  |  |  |  |  |
Current | 60 |  | 86 |  | — |  | — |  | 146 |
Long-term | 629 |  | 33 |  | — |  | — |  | 662 |
Other assets | — |  | — |  | 37 |  | 15 |  | 52 |
Financial liabilities |  |  |  |  |  |  |  |  |
Accounts payable and accrued liabilities | — |  | — |  | 497 |  | — |  | 497 |
Dividends payable | — |  | — |  | 58 |  | — |  | 58 |
Risk management liabilities |  |  |  |  |  |  |  |  |
Current | 1 |  | 89 |  | — |  | — |  | 90 |
Long-term | 1 |  | 40 |  | — |  | — |  | 41 |
Credit facilities, long-term debt and finance lease obligations(2) | — |  | — |  | 3,267 |  | — |  | 3,267 |
(1) Includes cash equivalents of nil. (2) Includes current portion.
Carrying value as at Dec. 31, 2017 |  |  |  |  |
| Derivatives used for hedging |  | Derivatives classified as held for trading |  | Loans and receivables |  | Other financial liabilities |  | Total |
Financial assets |  |  |  |  |  |  |  |  |  |
Cash and cash equivalents(1) | — |  | — |  | 314 |  | — |  | 314 |
Restricted cash | — |  | — |  | 30 |  | — |  | 30 |
Trade and other receivables | — |  | — |  | 933 |  | — |  | 933 |
Long-term portion of finance lease receivables | — |  | — |  | 215 |  | — |  | 215 |
Risk management assets |  |  |  |  |  |  |  |  |  |
Current | 82 |  | 137 |  | — |  | — |  | 219 |
Long-term | 638 |  | 46 |  | — |  | — |  | 684 |
Other assets | — |  | — |  | 33 |  | — |  | 33 |
Financial liabilities |  |  |  |  |  |  |  |  |  |
Accounts payable and accrued liabilities | — |  | — |  | — |  | 595 |  | 595 |
Dividends payable | — |  | — |  | — |  | 34 |  | 34 |
Risk management liabilities |  |  |  |  |  |  |  |  |  |
Current | 8 |  | 93 |  | — |  | — |  | 101 |
Long-term | 2 |  | 38 |  | — |  | — |  | 40 |
Credit facilities, long-term debt and finance lease obligations(2) | — |  | — |  | — |  | 3,707 |  | 3,707 |
(1) Includes cash equivalents of nil. (2) Includes current portion. B. Fair Value of Financial Instruments The fair value of a financial instrument is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair values can be determined by reference to prices for that instrument in active markets to which the Corporation has access. In the absence of an active market, the Corporation determines fair values based on valuation models or by reference to other similar products in active markets. Fair values determined using valuation models require the use of assumptions. In determining those assumptions, the Corporation looks primarily to external readily observable market inputs. However, if not available, the Corporation uses inputs that are not based on observable market data. I. Level I, II and III Fair Value Measurements The Level I, II and III classifications in the fair value hierarchy utilized by the Corporation are defined below. The fair value measurement of a financial instrument is included in only one of the three levels, the determination of which is based on the lowest level input that is significant to the derivation of the fair value. a. Level I Fair values are determined using inputs that are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Corporation has the ability to access at the measurement date. In determining Level I fair values, the Corporation uses quoted prices for identically traded commodities obtained from active exchanges such as the New York Mercantile Exchange. b. Level II Fair values are determined, directly or indirectly, using inputs that are observable for the asset or liability. Fair values falling within the Level II category are determined through the use of quoted prices in active markets, which in some cases are adjusted for factors specific to the asset or liability, such as basis, credit valuation and location differentials. The Corporation’s commodity risk management Level II financial instruments include over-the-counter derivatives with values based on observable commodity futures curves and derivatives with inputs validated by broker quotes or other publicly available market data providers. Level II fair values are also determined using valuation techniques, such as option pricing models and regression or extrapolation formulas, where the inputs are readily observable, including commodity prices for similar assets or liabilities in active markets, and implied volatilities for options. In determining Level II fair values of other risk management assets and liabilities, the Corporation uses observable inputs other than unadjusted quoted prices that are observable for the asset or liability, such as interest rate yield curves and currency rates. For certain financial instruments where insufficient trading volume or lack of recent trades exists, the Corporation relies on similar interest or currency rate inputs and other third-party information such as credit spreads. c. Level III Fair values are determined using inputs for the assets or liabilities that are not readily observable. The Corporation may enter into commodity transactions for which market-observable data is not available. In these cases, Level III fair values are determined using valuation techniques such as the Black-Scholes, mark-to-forecast and historical bootstrap models with inputs that are based on historical data such as unit availability, transmission congestion, demand profiles for individual non-standard deals and structured products, and/or volatilities and correlations between products derived from historical prices. The Corporation also has various commodity contracts with terms that extend beyond a liquid trading period. As forward market prices are not available for the full period of these contracts, the value of these contracts is derived by reference to a forecast that is based on a combination of external and internal fundamental modelling, including discounting. As a result, these contracts are classified in Level III. The Corporation has a Commodity Exposure Management Policy, that governs both the commodity transactions undertaken in its proprietary trading business and those undertaken to manage commodity price exposures in its generation business. This Policy defines and specifies the controls and management responsibilities associated with commodity trading activities, as well as the nature and frequency of required reporting of such activities. Methodologies and procedures regarding commodity risk management Level III fair value measurements are determined by the Corporation’s risk management department. Level III fair values are calculated within the Corporation’s energy trading risk management system based on underlying contractual data as well as observable and non-observable inputs. Development of non-observable inputs requires the use of judgment. To ensure reasonability, system-generated Level III fair value measurements are reviewed and validated by the risk management and finance departments. Review occurs formally on a quarterly basis or more frequently if daily review and monitoring procedures identify unexpected changes to fair value or changes to key parameters. Information on risk management contracts or groups of risk management contracts that are included in Level III measurements and the related unobservable inputs and sensitivities, is as follows, and excludes the effects on fair value of certain unobservable inputs such as liquidity and credit discount (described as “base fair values”), as well as inception gains or losses. Sensitivity ranges for the base fair values are determined using reasonably possible alternative assumptions for the key unobservable inputs, which may include forward commodity prices, commodity volatilities and correlations, delivery volumes, and shapes.
As at Dec. 31 | 2018 | 2017
Description | Base fair value |  | Sensitivity | Base fair value |  | Sensitivity |
Long-term power sale - US | 801 |  | +116 -116 | 853 |  | +130 -130 |
Long-term power sale - Alberta | 4 |  | +1 -1 | (1 | ) | +2 -2 |
Unit contingent power purchases | 18 |  | +4 -4 | 44 |  | +7 -9 |
Structured products - Eastern US | 6 |  | +5 -5 | 17 |  | +8 -7 |
Long-term wind energy sale - Eastern US | (39 | ) | +21 -21 | — |  | — |
Others | 4 |  | +3 -3 | 5 |  | +9 -9 |
i. Long-Term Power Sale - US The Corporation has a long-term fixed price power sale contract in the US for delivery of power at the following capacity levels: 380 MW through Dec. 31, 2024, and 300 MW through Dec. 31, 2025. The contract is designated as an all-in-one cash flow hedge. For periods beyond 2020, market forward power prices are not readily observable. For these periods, fundamental-based forecasts and market indications have been used to determine proxies for base, high and low power price scenarios. The base price forecast has been developed by using a fundamental-based forecast (the provider is an independent and widely accepted industry expert for scenario and planning views). Prior to the second quarter of 2018, the base price forecast was developed using an additional independent industry forecast. Forward power price ranges per MWh used in determining the Level III base fair value at Dec. 31, 2018, are US$20-US$35 (Dec. 31, 2017 - US$25-US$34). The sensitivity analysis has been prepared using the Corporation’s assessment that a US$6 (Dec. 31, 2017 - US$6) price increase or decrease in the forward power prices is a reasonably possible change. The contract is denominated in US dollars. With the strengthening of the US dollar relative to the Canadian dollar from Dec. 31, 2017 to Dec. 31, 2018, the base fair value and the sensitivity values have increased by approximately $62 million and $9 million, respectively. ii. Long-Term Power Sale - Alberta The Corporation has a long-term 12.5 MW fixed price power sale contract (monthly shaped) in the Alberta market through December 2024. The contract is accounted for as FVTPL. For periods beyond 2023, market forward power prices are not readily observable. For these periods, fundamental-based price forecasts and market indications have been used as proxies to determine base, high and low power price scenarios. The base scenario uses the most recent price view from an independent external forecasting service that is accepted within industry as an expert in the Alberta market. Forward power prices per MWh used in determining the Level III base fair value at Dec. 31, 2018, are $40 (Dec. 31, 2017 - $63 -$67). The sensitivity analysis has been prepared using the Corporation’s assessment that a 20 per cent increase or decrease in the forward power prices is a reasonably possible change. iii. Unit Contingent Power Purchases Under the unit contingent power purchase agreements, the Corporation has agreed to purchase power contingent upon the actual generation of specific units owned and operated by third parties. Under these types of agreements, the purchaser pays the supplier an agreed upon fixed price per MWh of output multiplied by the pro rata share of actual unit production (nil if a plant outage occurs). The contracts are accounted for as FVTPL. The key unobservable inputs used in the valuations are delivered volume expectations and hourly shapes of production. Hourly shaping of the production will result in realized prices that may be at a discount (or premium) relative to the average settled power price. Reasonably possible alternative inputs were used to determine sensitivity on the fair value measurements. This analysis is based on historical production data of the generation units for available history. Price and volumetric discount ranges per MWh used in the Level III base fair value measurement at Dec. 31, 2018, are nil (Dec. 31, 2017 - nil) and 2.2 per cent to 16.9 per cent (Dec. 31, 2017 – 2.2 per cent to 2.8 per cent), respectively. The sensitivity analysis has been prepared using the Corporation’s assessment of a reasonably possible change in price discount ranges of approximately 1.1 per cent to 1.9 per cent (Dec. 31, 2017 - 1.1 per cent to 1.9 per cent) and a change in volumetric discount rates of approximately 8.6 per cent to 27.3 per cent (Dec. 31, 2017 - 7.8 per cent and 10.5 per cent), which approximate one standard deviation for each input. iv. Structured Products - Eastern US The Corporation has fixed priced power and heat rate contracts in the eastern United States. Under the fixed priced power contracts, the Corporation has agreed to buy or sell power at non-liquid locations or during non-standard hours. The Corporation has also bought and sold heat rate contracts at both liquid and non-liquid locations. Under a heat rate contract, the buyer has the right to purchase power at times when the market heat rate is higher than the contractual heat rate. The key unobservable inputs in the valuation of the fixed priced power contracts are market forward spreads and non-standard shape factors. A historical regression analysis has been performed to model the spreads between non-liquid and liquid hubs. The non-standard shape factors have been determined using the historical data. Basis relationship and non-standard shape factors used in the Level III base fair value measurement at Dec. 31, 2018, are 75 per cent to 109 per cent and 63 per cent to 104 per cent (Dec. 31, 2017 – 75 per cent to 159 per cent and 71 per cent to 88 per cent), respectively. The sensitivity analysis has been prepared using the Corporation’s assessment of a reasonably possible change in market forward spreads of approximately 4 per cent to 7 per cent (Dec. 31, 2017 - 7 per cent) and a change in non-standard shape factors of approximately 4 per cent to 9 per cent (Dec. 31, 2017 - 6 per cent), which approximate one standard deviation for each input. The key unobservable inputs in the valuation of the heat rate contracts are implied volatilities and correlations. Implied volatilities and correlations used in the Level III base fair value measurement at Dec. 31, 2018, are 25 per cent to 84 per cent and 70 per cent (Dec. 31, 2017 – 18 per cent to 54 per cent and 70 per cent), respectively. The sensitivity analysis has been prepared using the Corporation’s assessment of a reasonably possible change in implied volatilities ranges and correlations of approximately 37 per cent to 49 per cent and 30 per cent, respectively (2017 - 27 per cent to 32 per cent and 10 per cent, respectively). v. Long-Term Wind Energy Sale - Eastern US In relation to the acquisition of Big Level (See Note 4(C)), the Corporation has a long-term contract for differences whereby the Corporation receives a fixed price per MWh and pays the prevailing real-time energy market price per MWh as well as the physical delivery of renewable energy credits ("RECs") based on proxy generation. Commercial operation of the facility is expected to occur in the second half of 2019, with the contract extending for 15 years after commercial operation. The contract is accounted for at fair value through profit or loss. The key unobservable inputs used in the valuation of the contract are expected proxy generation volumes and forward prices for power and RECs beyond 2023 and 2022, respectively. Forward power and REC price ranges per MWh used in determining the Level III base fair value at Dec. 31, 2018, are US$42-US$68 and US$7-US$8, respectively. The sensitivity analysis has been prepared using the Corporation’s assessment that a change in expected proxy generation volumes of 10 per cent, a change in energy prices of US$6 and a change in REC prices of US$1 as reasonably possible changes. II. Commodity Risk Management Assets and Liabilities Commodity risk management assets and liabilities include risk management assets and liabilities that are used in the energy marketing and generation businesses in relation to trading activities and certain contracting activities. To the extent applicable, changes in net risk management assets and liabilities for non-hedge positions are reflected within earnings of these businesses. Commodity risk management assets and liabilities classified by fair value levels as at Dec. 31, 2018, are as follows: Level I - $3 million net asset (Dec. 31, 2017 - $1 million net liability), Level II - $19 million net liability (Dec. 31, 2017 - $42 million net liability) and Level III - $695 million net asset (Dec. 31, 2017 - $771 million net asset). Significant changes in commodity net risk management assets (liabilities) during the year ended Dec. 31, 2018, are primarily attributable to the settlement of contracts, partially offset by favourable foreign exchange rates. The following tables summarize the key factors impacting the fair value of the Level III commodity risk management assets and liabilities by classification level during the years ended Dec. 31, 2018 and 2017, respectively:
| Year ended Dec. 31, 2018 |  | Year ended Dec. 31, 2017
| Hedge |  | Non-hedge |  | Total |  |  | Hedge |  | Non-hedge |  | Total |
Opening balance | 719 |  | 52 |  | 771 |  |  | 726 |  | 32 |  | 758 |
Changes attributable to: |  |  |  |  |  |  |
Market price changes on existing contracts | (7 | ) | (9 | ) | (16 | ) |  | 100 |  | (2 | ) | 98 |
Market price changes on new contracts | — |  | 4 |  | 4 |  |  | — |  | 33 |  | 33 |
Contracts settled | (90 | ) | (42 | ) | (132 | ) |  | (57 | ) | (10 | ) | (67 | )
Change in foreign exchange rates | 67 |  | 5 |  | 72 |  |  | (50 | ) | (2 | ) | (52 | )
Transfers into (out of) Level III | — |  | (4 | ) | (4 | ) |  | — |  | 1 |  | 1 |
Net risk management assets at end of period | 689 |  | 6 |  | 695 |  |  | 719 |  | 52 |  | 771 |
Additional Level III information: |  |  |  |  |  |  |
Gains recognized in other comprehensive income | 60 |  | — |  | 60 |  |  | 50 |  | — |  | 50 |
Total gains included in earnings before income taxes | 90 |  | — |  | 90 |  |  | 57 |  | 29 |  | 86 |
Unrealized gains (losses) included in earnings before income taxes relating to net assets held at period end | — |  | (42 | ) | (42 | ) |  | — |  | 19 |  | 19 |
III. Other Risk Management Assets and Liabilities Other risk management assets and liabilities primarily include risk management assets and liabilities that are used in managing exposures on non-energy marketing transactions such as interest rates, the net investment in foreign operations and other foreign currency risks. Hedge accounting is not always applied. Other risk management assets and liabilities with a total net liability fair value of $2 million as at Dec. 31, 2018 (Dec. 31, 2017 - $34 million net asset) are classified as Level II fair value measurements. The significant changes in other net risk management assets during the year ended Dec. 31, 2018, are primarily attributable to the settlement of contracts. IV. Other Financial Assets and Liabilities The fair value of financial assets and liabilities measured at other than fair value is as follows:
| Fair value(1) | Total carrying |
| Level I |  | Level II |  | Level III |  | Total |  | value(1) |
Long-term debt - Dec. 31, 2018 | — |  | 3,181 |  | — |  | 3,181 |  | 3,204 |
Long-term debt - Dec. 31, 2017 | — |  | 3,708 |  | — |  | 3,708 |  | 3,638 |
(1) Includes current portion. The fair values of the Corporation’s debentures and senior notes are determined using prices observed in secondary markets. Non-recourse and other long-term debt fair values are determined by calculating an implied price based on a current assessment of the yield to maturity. The carrying amount of other short-term financial assets and liabilities (cash and cash equivalents, trade accounts receivable, collateral paid, accounts payable and accrued liabilities, collateral received and dividends payable) approximates fair value due to the liquid nature of the asset or liability. The fair values of the loan receivable (see Note 20) and the finance lease receivables (see Note 8) approximate the carrying amounts. C. Inception Gains and Losses The majority of derivatives traded by the Corporation are based on adjusted quoted prices on an active exchange or extend beyond the time period for which exchange-based quotes are available. The fair values of these derivatives are determined using inputs that are not readily observable. Refer to section B of this note for fair value Level III valuation techniques used. In some instances, a difference may arise between the fair value of a financial instrument at initial recognition (the “transaction price”) and the amount calculated through a valuation model. This unrealized gain or loss at inception is recognized in net earnings (loss) only if the fair value of the instrument is evidenced by a quoted market price in an active market, observable current market transactions that are substantially the same, or a valuation technique that uses observable market inputs. Where these criteria are not met, the difference is deferred on the Consolidated Statements of Financial Position in risk management assets or liabilities, and is recognized in net earnings (loss) over the term of the related contract. The difference between the transaction price and the fair value determined using a valuation model, yet to be recognized in net earnings, and a reconciliation of changes is as follows:
As at Dec. 31 | 2018 |  | 2017 |  | 2016 |
Unamortized net gain at beginning of year | 105 |  | 148 |  | 202 |
New inception gains (losses) | (14 | ) | 12 |  | 10 |
Change in foreign exchange rates | 5 |  | (7 | ) | (4 | )
Amortization recorded in net earnings during the year | (47 | ) | (48 | ) | (60 | )
Unamortized net gain at end of year | 49 |  | 105 |  | 148 |

X
- References No definition available. + Details
Name: | ifrs-full_DisclosureOfFinancialInstrumentsAbstract
Namespace Prefix: | ifrs-full_
Data Type: | xbrli:stringItemType
Balance Type: | na
Period Type: | duration

X
- Definition The entire disclosure for financial instruments. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Name IFRS -Number 7 -IssueDate 2017-01-01 -Section Scope -URI http://eifrs.ifrs.org/eifrs/XBRL?type=IFRS&num=7&date=2017-03-01&anchor=sect_Scope&doctype=Standard -URIDate 2017-03-09 + Details
Name: | ifrs-full_DisclosureOfFinancialInstrumentsExplanatory
Namespace Prefix: | ifrs-full_
Data Type: | nonnum:textBlockItemType
Balance Type: | na
Period Type: | duration