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Financial Instruments
 12 Months Ended
Dec. 31, 2023
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.
Carrying value as at Dec. 31, 2023Derivatives
used for
hedging		Derivatives
held for
trading (FVTPL)		Amortized costOther financial assets (FVTPL)Other financial assets (FVOCI)Total
Financial assets    
Cash and cash equivalents(1)
— — 348 — — 348 
Restricted cash— — 69 — — 69 
Trade and other receivables— — 807 — — 807 
Long-term portion of finance lease receivables— — 171 — — 171 
Long-term portion of loan receivable(2)
— — 25 — — 25 
Other investments(3)
— — — 15 1 16 
Risk management assets    
Current— 151 — — — 151 
Long-term— 52 — — — 52 
Financial liabilities    
Bank overdraft— — 3 — — 3 
Accounts payable and accrued liabilities
— — 797 — — 797 
Dividends payable— — 49 — — 49 
Risk management liabilities   
Current125 189 — — — 314 
Long-term80 194 — — — 274 
Credit facilities, long-term debt and lease liabilities(4)
— — 3,466 — — 3,466 
Exchangeable securities— — 744 — — 744 
(1)Includes cash equivalents of nil.
(2)Included in other assets. Refer to Note 22.
(3)Included in investments. Refer to Note 9.
(4)Includes current portion.
Carrying value as at Dec. 31, 2022Derivatives
used for
hedging		Derivatives
held for
trading (FVTPL)		Amortized costOther financial assets (FVTPL)Other financial assets (FVTOCI)Total
Financial assets    
Cash and cash equivalents(1)
— — 1,134 — — 1,134 
Restricted cash— — 70 — — 70 
Trade and other receivables— — 1,589 — — 1,589 
Long-term portion of finance lease receivables— — 129 — — 129 
Long-term portion of loan receivable(2)
— — 33 — — 33 
Other investments(3)
— — — 11 1 12 
Risk management assets
Current— 709 — — — 709 
Long-term— 161 — — — 161 
Financial liabilities    
Bank overdraft— — 16 — — 16 
Accounts payable and accrued liabilities— — 1,346 — — 1,346 
Dividends payable— — 68 — — 68 
Risk management liabilities
Current271 858 — — — 1,129 
Long-term76 257 — — — 333 
Credit facilities, long-term debt and lease liabilities(4)
— — 3,653 — — 3,653 
Exchangeable securities— — 739 — — 739 
(1)Includes cash equivalents of nil.
(2)Included in other assets. Refer to Note 22.
(3)Included in investments. Refer to Note 9.
(4)Includes current portion.
B. Fair Value of Financial Instruments
The fair value of a financial instrument is the price that would be received when selling the asset or paid to transfer the associated liability in an orderly transaction between market participants at the measurement date. Fair values can be determined by observing quoted prices for the instrument in active markets to which the Company has access. In the absence of an active market, the Company 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 Company looks primarily to external readily observable market inputs. However, if not available, the Company 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 Company 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. The Level III classification is the lowest level classification in the fair value hierarchy.
a. Level I
Fair values are determined using inputs that are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date. In determining Level I fair values, the Company 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 Company’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 interpolation formulas, where the inputs are readily observable.
In determining Level II fair values of other risk management assets and liabilities, the Company 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 Company 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 Company 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 mark-to-forecast and mark-to-model. For mark-to-model valuations, derivative pricing models, regression-based models and scenario analysis simulation models may be employed. The model inputs may be based on historical data such as unit availability, transmission congestion, demand profiles for individual non-standard deals and structured products and/or volatility and correlations between products derived from historical price relationships. For assets and liabilities that are recognized at fair value on a recurring basis, the Company determines whether transfers have occurred between levels in the hierarchy by re-assessing categorization (based on the lowest level input that is significant to the fair value measurement as a whole) at the end of each reporting period.
The Company 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.
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 segments 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, 2023, are as follows: Level I – $13 million net liability (Dec. 31, 2022 – $23 million net asset), Level II – $244 million net liability (Dec. 31, 2022 – $173 million net asset) and Level III – $147 million net liability (Dec. 31, 2022 – $782 million net liability).
Significant changes in commodity net risk management assets (liabilities) during the year ended Dec. 31, 2023, are primarily attributable to contract settlements and volatility in market prices across multiple markets on both existing contracts and new contracts.
The following table summarizes the key factors impacting the fair value of the Level III commodity risk management assets and liabilities by classification during the years ended Dec. 31, 2023 and 2022, respectively:
Year ended Dec. 31, 2023Year ended Dec. 31, 2022
HedgeNon-hedgeTotalHedgeNon-hedgeTotal
Opening balance(347)(435)(782)285 (126)159 
Changes attributable to:
Market price changes on existing contracts(123)(6)(129)(611)(298)(909)
Market price changes on new contracts
— 18 18 — (124)(124)
Contracts settled256 269 525 (38)118 80 
Change in foreign exchange rates9 7 16 17 (5)12 
Transfers out of Level III(1)
205 — 205 — — — 
Net risk management assets (liabilities) at end of year
— (147)(147)(347)(435)(782)
Additional Level III information:
Losses recognized in other comprehensive loss(114)— (114)(594)— (594)
Total gains (losses) included in earnings before income taxes
(256)19 (237)38 (427)(389)
Unrealized gains (losses) included in earnings before income taxes relating to net assets (liabilities) held at year end
— 288 288 — (309)(309)
(1)The Company has a long-term fixed price power sale contract in the US for delivery of power. The fair value of this instrument was transferred out of Level III to Level II as at Dec. 31, 2023 as the forward price curve is now based on observable market prices for the remaining duration of the contract.

The Company 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. 
The Company's risk management department determines methodologies and procedures regarding commodity risk management Level III fair value measurements. Level III fair values are primarily calculated within the Company’s energy trading risk management processes. These calculations are 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, the 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.
As at Dec. 31, 2023, the total Level III risk management asset balance was $56 million (Dec. 31, 2022 – $31 million) and Level III risk management liability balance was $203 million (Dec. 31, 2022 – $813 million). The net risk management liabilities decreased mainly due to market price changes and settled contracts. The 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 are outlined in the following table. These include the effects on fair value of discounting, liquidity and credit value adjustments; however, the potential offsetting effects of Level II positions are not considered. 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, volatility in commodity prices and correlations, delivery volumes, escalation rates and cost of supply.
As atDec. 31, 2023
DescriptionValuation techniqueUnobservable inputReasonably possible change
Sensitivity(1)
Coal transportation – USNumerical
derivative valuation		Volatility
80% to 120%
+6
Rail rate escalation
zero to 10%
-4
Full requirements – Eastern US
Scenario analysisVolume
96% to 104%
+3
Cost of supply
Decrease of $2.30 per MWh
or increase of $2.40 per MWh
-3
Long-term wind energy sale – Eastern US
Long-term price forecastIlliquid future power prices (per MWh)
Price decrease
or increase of US$6
+24
Illiquid future REC prices (per unit)
Price decrease of US$12
or increase of US$8
Wind discounts
0% decrease or 9% increase
-28
Long-term wind energy sale – Canada
Long-term price forecastIlliquid future power prices (per MWh)
Price decrease of C$81
or increase of C$5
+65 
Wind discounts
 16% decrease or 5% increase
-23 
Long-term wind energy sale - Central US
Long-term price forecastIlliquid future power prices (per MWh)
Price decrease of US$1
or increase of US$2
+81 
Wind discounts
5% decrease or 2% increase
-36 
(1)Sensitivity represents the total increase or decrease in recognized fair value that could arise from the use of the reasonably possible changes of all unobservable inputs.
As atDec. 31, 2022
DescriptionValuation
technique		Unobservable inputReasonably possible change
Sensitivity(1)
Coal transportation – US
Numerical derivative valuationIlliquid future power prices (per MWh)
Price decrease of US$5
or increase of US$55
+14
Volatility
80% to 120%
Rail rate escalation
zero to 10%
-13
Full requirements - Eastern US
Scenario analysisVolume
96% to 104%
+3
Cost of supply
Decrease of US$0.50 per MWh
or increase of US$3.30 per MWh
-21
Long-term wind energy sale – Eastern US
Long-term price forecastIlliquid future power prices (per MWh)
Price decrease
or increase of US$6
+22
Illiquid future REC prices (per unit)
Price decrease
or increase of US$2
Wind discounts
0% decrease or 5% increase
-18
Long-term wind energy sale – Canada
Long-term price forecastIlliquid future power prices (per MWh)
Price decrease of C$85
or increase of C$5
+47
Wind discounts
28% decrease or 5% increase
-25
Long-term wind energy sale – Central USLong-term price forecastIlliquid future power prices (per MWh)
Price decrease
or increase of US$2
+74
Wind discounts
2% decrease or 5% increase
-28
Long-term power
sale – US
Long-term price forecastIlliquid future power prices (per MWh)
Price decrease of US$5
or increase of US$55
+15
-163
(1)Sensitivity represents the total increase or decrease in recognized fair value that would arise from the use of the reasonably possible changes of all unobservable inputs.
a. Coal Transportation – US
The Company has a coal rail transport agreement that includes an upside sharing mechanism until Dec. 31, 2025. Option pricing techniques have been utilized to value the obligation associated with this component of the agreement.
The key unobservable inputs used in the valuation include option volatility and rail rate escalation. Option volatility and rail rate escalation ranges have been determined based on historical data and professional judgment.
In the first three quarters of 2023, non-liquid power prices were also used as a key unobservable input. At Dec. 31, 2023, the relevant forward power prices were observable in the market.
b. Full Requirements – Eastern US
The Company has a portfolio of full requirement service contracts, whereby the Company agrees to supply specific utility customer needs for a range of products that may include electrical energy, capacity, transmission, ancillary services, renewable energy credits ("RECs") and independent system operator costs.
The key unobservable inputs used in the portfolio valuation include delivered volume and supply cost. Hourly shaping of consumption will result in a realized cost that may be at a premium (or discount) relative to the average settled price.
c. Long-Term Wind Energy Sale – Eastern US
The Company is party to a long-term contract for differences ("CFD") for the offtake of 100 per cent of the generation from its 90 MW Big Level wind facility. The CFD, together with the sale of electricity generated into the PJM Interconnection at the prevailing real-time energy market price, achieve the fixed contract price per MWh on proxy generation. Under the CFD, if the market price is lower than the fixed contract price the customer pays the Company the difference and if the market price is higher than the fixed contract price the Company refunds the difference to the customer. The customer is also entitled to the physical delivery of environmental attributes. The contract matures in December 2034. The contract is accounted for as a derivative. Changes in fair value are presented in revenue.
The key unobservable inputs used in the valuation of the contract are expected proxy generation volumes and non-liquid forward prices for power, RECs and wind discounts.
d. Long-Term Wind Energy Sale – Canada
The Company is party to two Virtual Power Purchase Agreements ("VPPAs") for the offtake of 100 per cent of the generation from its 130 MW Garden Plain wind facility. The VPPAs, together with the sale of electricity generated into the Alberta power market at the pool price, achieve the fixed contract prices per MWh. Under the VPPAs, if the pool price is lower than the fixed contract price the customer pays the Company the difference and if the pool price is higher than the fixed contract price the Company refunds the difference to the customer. The customers are also entitled to the physical delivery of environmental attributes. Both VPPAs commenced on commercial operation of the facility which was achieved in August 2023, and extend for a weighted average of approximately 17 years.
The energy components of these contracts are accounted for as derivatives. Changes in fair value are presented in revenue.
The key unobservable inputs used in the valuations of the contracts are the non-liquid forward prices for power and monthly wind discounts.
e. Long-Term Wind Energy Sale – Central US
The Company is party to two long-term VPPAs for the offtake of 100 per cent of the generation from its 300 MW White Rock East and White Rock West wind power projects. The VPPAs, together with the sale of electricity generated into the US Southwest Power Pool ("SPP") market at the relevant price nodes, achieve the fixed contract prices per MWh. Under the VPPAs, if the SPP pricing is lower than the fixed contract price the customers pay the Company the difference, and if the SPP pricing is higher than the fixed contract price, the Company refunds the difference to the customers. The customer is also entitled to the physical delivery of environmental attributes. During the fourth quarter of 2023, the Company and the customer for the White Rock wind projects amended the associated VPPAs. The VPPAs commence on commercial operation of the facilities.
The Company is also party to a VPPA for the offtake of 100 per cent of the generation from its 200 MW Horizon Hill wind power project. The VPPA, together with the sale of electricity generated into the SPP market at the relevant price node, achieve the fixed contract price per MWh. Under the VPPA, if the SPP pricing is lower than the fixed contract price the customer pays the Company the difference and if the SPP pricing is higher than the fixed contract price the Company refunds the difference to the customer. The customer remains entitled to the physical delivery of environmental attributes. During the second quarter of 2023, the Company and the customer for the
Horizon Hill wind project amended the associated VPPA. The VPPA commences on commercial operation of the facility. Commissioning of the Horizon Hill wind project is expected during the first quarter of 2024.
The energy components of these contracts are accounted for as derivatives. Changes in fair value are presented in revenue. The amendments to the Horizon Hill and White Rock VPPAs did not change the nature of the contracts and the energy components continue to be accounted for as derivatives.
The key unobservable inputs used in the valuation of the contracts are the non-liquid forward prices for power and wind discounts.
f. Long-Term Power Sale – US
The Company 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.
At Dec. 31, 2023, the contract was transferred to Level II as all significant inputs were observable. In the first three quarters of 2023, the term of the transaction extended beyond where the relevant forward power prices were observable in the market.
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 asset fair value of $19 million as at Dec. 31, 2023 (Dec. 31, 2022 – $6 million net liability) are classified as Level II fair value measurements. The changes in other net risk management assets and liabilities during the year ended Dec. 31, 2023, are attributable to favourable market price changes on existing contracts, favourable foreign exchange rates on new contracts entered into during 2023, and contracts settled during 2023.
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
value(1)
 Level ILevel IILevel IIITotal
Exchangeable securities — Dec. 31, 2023— 718 — 718 744 
Long-term debt — Dec. 31, 2023— 3,104 — 3,104 3,323 
Loan receivable — Dec. 31, 2023— 26 — 26 26 
Exchangeable securities — Dec. 31, 2022— 685 — 685 739 
Long-term debt — Dec. 31, 2022— 3,200 — 3,200 3,518 
Loan receivable — Dec. 31, 2022— 37 — 37 37 
(1)Includes current portion.
The fair values of the Company’s debentures, senior notes and exchangeable securities 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, restricted cash, trade accounts receivable, collateral provided, bank overdraft, accounts payable and accrued liabilities, collateral held and dividends payable) approximates fair value due to the liquid nature of the asset or liability. The fair values of the finance lease receivables approximate the carrying amounts as the amounts receivable represent cash flows from repayments of principal and interest.
C. Inception Gains and Losses
The majority of derivatives traded by the Company 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 14 above 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 (loss) and a reconciliation of changes is as follows:
As at Dec. 31202320222021
Unamortized net loss at beginning of year
(213)(131)(33)
New inception gains (losses)(1)
47 (37)(79)
Change resulting from amended contract(2)
190 — — 
Change in foreign exchange rates6 (10)— 
Amortization recorded in net earnings during the year(27)(35)(19)
Unamortized net gain (loss) at end of year3 (213)(131)
(1)During 2023, the Company entered into long-term fixed price power sale contracts with certain of its US customers and as a result recognized day one inception gains that are based on the forward price curve at the inception of the contract. During 2022, the Company entered into a PPA for the Horizon Hill wind project (2021 – PPAs for the White Rock wind projects) that resulted in new inception losses due to the difference between the fixed PPA price and future estimated market prices. There are other key factors, such as project economics and incentives, that influence the long-term power price for renewable projects outside of the power price curve, which is not liquid for the majority of the duration of the PPA.
(2)During 2023, the Company entered into certain contract amendments related to the Horizon Hill and White Rock wind projects. These amendments were mainly specific to obtaining price increases over the contract term. Accordingly, certain inception loss calibration adjustments were recognized within the risk management liability.