

2019	Carrying amount		Fair value		Level 1		Level 2		Level 3
Long-term investments carried at fair value	$	1,294,147	$	1,294,147	1,178,581		$	27,072	$	88,494
Development loans and other receivables	37,050		37,984		—		37,984		—
Derivative instruments:
Energy contracts designated as a cash flow hedge	65,304		65,304		—		—		65,304
Energy contracts not designated as a hedge	20,384		20,384		—		—		20,384
Commodity contracts for regulated operations	16		16		—		16		—
Total derivative instruments	85,704		85,704		—		16		85,688
Total financial assets	$	1,416,901	$	1,417,835	$	1,178,581	$	65,072	$	174,182
Long-term debt	$	3,931,868	$	4,284,068	$	1,495,153	$	2,788,915	$	—
Convertible debentures	342		623		623		—		—
Preferred shares, Series C	13,793		15,120		—		15,120		—
Derivative instruments:
Energy contracts designated as a cash flow hedge	789		789		—		—		789
Energy contracts not designated as a hedge	38		38		—		—		38
Cross-currency swap designated as a net investment hedge	81,765		81,765		—		81,765		—
Commodity contracts for regulated operations	2,072		2,072		—		2,072		—
Total derivative instruments	84,664		84,664		—		83,837		827
Total financial liabilities	$	4,030,667	$	4,384,475	$	1,495,776	$	2,887,872	$	827

(a)Fair value of financial instruments (continued)



2018	Carrying amount		Fair value		Level 1		Level 2		Level 3
Long-term investment carried at fair value	$	814,530	$	814,530	$	814,530	$	—	$	—
Development loans and other receivables	103,696		110,019		—		110,019		—
Derivative instruments ⁽¹⁾:
Energy contracts designated as a cash flow hedge	61,838		61,838		—		—		61,838
Currency forward contract not designated as a hedge	869		869		—		869		—
Commodity contracts for regulatory operations	101		101		—		101		—
Total derivative instruments	62,808		62,808		—		970		61,838
Total financial assets	$	981,034	$	987,357	$	814,530	$	110,989	$	61,838
Long-term debt	$	3,336,795	$	3,356,773	$	768,400	$	2,588,373	$	—
Convertible debentures	470		639		639		—		—
Preferred shares, Series C	13,418		13,703		—		13,703		—
Derivative instruments:
Energy contracts designated as a cash flow hedge	57		57		—		—		57
Cross-currency swap designated as a net investment hedge	93,198		93,198		—		93,198		—
Interest rate swaps designated as a hedge	8,473		8,473		—		8,473		—
Commodity contracts for regulated operations	1,114		1,114		—		1,114		—
Total derivative instruments	102,842		102,842		—		102,785		57
Total financial liabilities	$	3,453,525	$	3,473,957	$	769,039	$	2,704,861	$	57

The Company’s level 1 fair value of long-term debt is measured at the closing price on the NYSE and the Canadian over-the-counter closing price. The Company’s level 2 fair value of long-term debt at fixed interest rates and Series C preferred shares has been determined using a discounted cash flow method and current interest rates. The Company's level 2 fair value of convertible debentures has been determined as the greater of their face value and the quoted value of APUC's common shares on a converted basis.

The Company’s level 2 fair value derivative instruments primarily consist of swaps, options, rights and forward physical derivatives where market data for pricing inputs are observable. Level 2 pricing inputs are obtained from various market indices and utilize discounting based on quoted interest rate curves which are observable in the marketplace.

The Company’s level 3 instruments consist of energy contracts for electricity sales and the fair value of the Company's investment in AYES Canada. The significant unobservable inputs used in the fair value measurement of energy contracts are the internally developed forward market prices ranging from $13.33 to $178.65 with a weighted average of $23.66 as of December 31, 2019. The weighted average forward market prices are developed based on the quantity of energy expected to be sold monthly and the expected forward price during that month. The change in the fair value of the energy contracts is detailed in notes 24(b)(ii) and 24(b)(iv). The significant unobservable inputs used in the fair value measurement of the Company's AYES Canada investment are the expected cash flows, the discount rates applied to these cash flows ranging from 8.75% to 9.50% with a weighted average of 9.42%, and the expected volatility of Atlantica's share price ranging from 18% to 22% as of December 31, 2019. Significant increases (decreases) in expected cash flows or increases (decreases) in discount rate in isolation would have resulted in a significantly lower (higher) fair value measurement.

The Company uses derivative financial instruments to reduce the cash flow variability associated with the purchase price for a portion of future natural gas purchases associated with its regulated gas and electric service territories. The Company’s strategy is to minimize fluctuations in gas sale prices to regulated customers.

The accounting for these derivative instruments is subject to guidance for rate regulated enterprises. Therefore, the fair value of these derivatives is recorded as current or long-term assets and liabilities, with offsetting positions recorded as regulatory assets and regulatory liabilities in the consolidated balance sheets. Most of the gains or losses on the settlement of these contracts are included in the calculation of the fuel and commodity costs adjustments (note 7(e)). As a result, the changes in fair value of these natural gas derivative contracts and their offsetting adjustment to regulatory assets and liabilities had no earnings impact.

In January 2019, the Company entered into a long-term energy derivative contract to reduce the price risk on the expected future sale of power generation at Sugar Creek. On September 30, 2019, the Company sold the derivative contract together with 100% of its ownership interest in Sugar Creek to AAGES Sugar Creek. The novation and transfer of the derivative contract was subject to counterparty approval, which was received subsequent to year-end in Q1 2020. As a result, the hedge relationship for the Sugar Creek energy derivative was discontinued. Amounts in AOCI of $15,765 and related tax were reclassified from AOCI into earnings in 2019 (note 24(b)(iv)).

During the year, the Company entered into an energy derivative contract to reduce the price risk on the expected future purchase of power on the open market at its Tinker Hydroelectric Facility with a notional quantity of 151,680 MW-hours and a price of $38.95 per MW-hr. The contract expires February 2022.

The Company was party to a 10-year forward-starting interest rate swap beginning on July 25, 2018 in order to reduce the interest rate risk related to the probable issuance on that date of a 10-year C$135,000 bond. During 2018, the Company amended and extended the forward-starting date of the interest rate swap to begin on March 29, 2019. During the year, the Company settled the forward-starting interest rate swap contract as it issued C$300,000 10-year senior unsecured notes with an interest rate of 4.60% (note 9(d)).

On May 23, 2019, the Company entered into a cross-currency swap, coterminous with the subordinated unsecured notes (note 9(e)), to effectively convert the $350,000 U.S. dollar denominated offering into Canadian dollars. The change in the carrying amount of the notes due to changes in spot exchange rates is recognized each period in the consolidated statements of operations as loss (gain) on foreign exchange. The Company designated the entire notional amount of the cross-currency fixed-for-fixed interest rate swap as a hedge of the foreign currency exposure related to cash flows for the interest and principal repayments on the notes. The gain or loss related to the fair value changes of the swap is first reported in OCI and a portion of the change is then reclassified from AOCI into earnings at each reporting date to offset the foreign exchange transaction gain or loss on the notes.

In September 2019, the Company entered into a forward-starting interest rate swap in order to reduce the interest rate risk related to the quarterly interest payments between July 1, 2024 and July 1, 2029 on the subordinated unsecured notes (note 9(e)). The Company designated the entire notional amount of the three pay-variable and receive-fixed interest rate swaps as a hedge of the future quarterly variable-rate interest payments associated with the subordinated unsecured notes.

The Company is exposed to currency fluctuations from its Canadian-based operations. APUC manages this risk primarily through the use of natural hedges by using Canadian long-term debt to finance its Canadian operations and a combination of foreign exchange forward contracts and spot purchases. APUC only enters into foreign exchange forward contracts with major North American financial institutions having a credit rating of A or better, thus reducing credit risk on these forward contracts.

The Company’s Canadian operations are determined to have the Canadian dollar as their functional currency and are exposed to currency fluctuations from their U.S. dollar transactions. The Company designates the amounts drawn on its revolving and bank credit facilities denominated in U.S. dollars as a hedge of the foreign currency exposure of its net investment in its U.S. investments and subsidiaries. The related foreign currency transaction gain or loss designated as, and effective as, a hedge of the net investment in a foreign operation are reported in the same manner as the translation adjustment (in OCI) related to the net investment. A foreign currency gain of $35,277 for the year ended December 31, 2019 (2018 - loss of $28,705) was recorded in OCI.

Concurrent with its C$150,000, C$200,000 and C$300,000 debenture offerings in December 2012, January 2014, and January 2017, respectively, the Company entered into cross currency swaps, coterminous with the debentures, to effectively convert the Canadian dollar denominated offering into U.S. dollars. The Company designated the entire notional amount of the cross-currency fixed-for-fixed interest rate swap and related short-term U.S. dollar payables created by the monthly accruals of the swap settlement as a hedge of the foreign currency exposure of its net investment in the Renewable Energy Group's U.S. operations. The gain or loss related to the fair value changes of the swap and the related foreign currency gains and losses on the U.S. dollar accruals that are designated as, and are effective as, a hedge of the net investment in a foreign operation are reported in the same manner as the translation adjustment (in OCI) related to the net investment. A gain of $15,946 (2018 - loss of $41,244) was recorded in OCI in 2019.

The Company provides energy requirements to various customers under contracts at fixed rates. While the production from the Tinker Hydroelectric Facility is expected to provide a portion of the energy required to service these customers, APUC anticipates having to purchase a portion of its energy requirements at the ISO NE spot rates to supplement self-generated energy.

This risk is mitigated through the use of short-term financial forward energy purchase contracts that are classified as derivative instruments. The electricity derivative contracts are net settled fixed-for-floating swaps whereby APUC pays a fixed price and receives the floating or indexed price on a notional quantity of energy over the remainder of the contract term at an average rate, as per the following table. These contracts are not accounted for as hedges and changes in fair value are recorded in earnings as they occur.

The Company is exposed to foreign exchange fluctuations related to the portion of its dividend declared and payable in U.S. dollars. This risk is mitigated through the use of currency forward contracts. For the year ended December 31, 2019, a foreign exchange loss of $983 (2018 - gain of $1,115) was recorded in the consolidated statements of operations. These currency forward contracts are not accounted for as a hedge.



	2019			2018
Change in unrealized loss (gain) on derivative financial instruments:
Energy derivative contracts	$	(530	)	$	77
Currency forward contract	904			(1,230		)
Total change in unrealized loss (gain) on derivative financial instruments	$	374		$	(1,153	)
Realized loss (gain) on derivative financial instruments:
Energy derivative contracts	227			(73		)
Currency forward contract	(147		)	115
Total realized loss on derivative financial instruments	$	80		$	42
Loss (gain) on derivative financial instruments not accounted for as hedges	454			(1,111		)
Discontinued hedge accounting (note 24(b)(ii)) and other	(15,810		)	632
	$	(15,356	)	$	(479	)
Amounts recognized in the consolidated statements of operations consist of:
Loss (gain) on derivative financial instruments	$	(16,113	)	$	636
Loss (gain) on foreign exchange	757			(1,115		)
	$	(15,356	)	$	(479	)

In the normal course of business, the Company is exposed to financial risks that potentially impact its operating results. The Company employs risk management strategies with a view of mitigating these risks to the extent possible on a cost effective basis. Derivative financial instruments are used to manage certain exposures to fluctuations in exchange rates, interest rates and commodity prices. The Company does not enter into derivative financial agreements for speculative purposes.

Credit risk is the risk of an unexpected loss if a customer or counterparty to a financial instrument fails to meet its contractual obligations. The Company’s financial instruments that are exposed to concentrations of credit risk are primarily cash and cash equivalents, accounts receivable, notes receivable and derivative instruments. The Company limits its exposure to credit risk with respect to cash equivalents by ensuring available cash is deposited with its senior lenders, all of which have a credit rating of A or better. The Company does not consider the risk associated with the Renewable Energy Group accounts receivable to be significant as over 87% of revenue from power generation is earned from large utility customers having a credit rating of Baa2 or better by Moody's, or BBB or higher by S&P, or BBB or higher by DBRS. Revenue is generally invoiced and collected within 45 days.

The remaining revenue is primarily earned by the Regulated Services Group, which consists of water and wastewater, electric and gas utilities in the United States and Canada. In this regard, the credit risk related to the Regulated Services Group accounts receivable balances of $200,594 is spread over thousands of customers. The Company has processes in place to monitor and evaluate this risk on an ongoing basis including background credit checks and security deposits from new customers. In addition, the regulators of the Regulated Services Group allow for a reasonable bad debt expense to be incorporated in the rates and therefore recovered from rate payers.

In addition, the Company continuously monitors the creditworthiness of the counterparties to its foreign exchange, interest rate, and energy derivative contracts prior to settlement, and assesses each counterparty’s ability to perform on the transactions set forth in the contracts. The counterparties consist primarily of financial institutions. This concentration of counterparties may impact the Company’s overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.

Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they fall due. The Company’s approach to managing liquidity risk is to ensure, to the extent possible, that it will always have sufficient liquidity to meet liabilities when due. As of December 31, 2019, in addition to cash on hand of $62,485, the Company had $1,047,216 available to be drawn on its senior debt facilities. Each of the Company’s revolving credit facilities contain covenants that may limit amounts available to be drawn.



	Due less than 1 year			Due 2 to 3 years		Due 4 to 5 years		Due after 5 years		Total
Long-term debt obligations	$	602,028		$	468,740	$	600,721	$	2,260,416	$	3,931,905
Convertible debentures	—		—	—		—		346		346
Advances in aid of construction	1,165			—		—		59,663		60,828
Interest on long-term debt	185,231			318,469		257,443		992,116		1,753,259
Purchase obligations	458,288			—		—		—		458,288
Environmental obligation	14,970			20,850		1,128		21,536		58,484
Derivative financial instruments:
Cross-currency swap	4,149			69,099		3,851		4,666		81,765
Energy derivative and commodity contracts	1,631			909		—		359		2,899
Other obligations	39,115			2,120		2,696		109,094		153,025
Total obligations	$	1,306,577		$	880,187	$	865,839	$	3,448,196	$	6,500,799