Enhanced Investments - Financial Portal

Published: 2022-05-06














		ENBRIDGE INC.

				CONSOLIDATED FINANCIAL STATEMENTS

		(unaudited)

		March 31, 2022

ENBRIDGE INC.
	CONSOLIDATED STATEMENTS OF EARNINGS
		Three months ended
			March 31,
			2022	2021
					(unaudited; millions of Canadian dollars, except per share amounts)Operating revenues
					Commodity sales	8,325		6,429
					Gas distribution sales	2,098		1,540
					Transportation and other services	4,674		4,168
					Total operating revenues (Note 3)	15,097		12,137
					Operating expenses
					Commodity costs	8,291		6,198
					Gas distribution costs	1,456		950
					Operating and administrative	1,875		1,559
					Depreciation and amortization	1,055		932
					Total operating expenses	12,677		9,639
					Operating income	2,420		2,498
					Income from equity investments	491	395
					Other income
					Net foreign currency gain	369	152
					Other	89	109
					Interest expense	(719)	(657)
					Earnings before income taxes	2,650		2,497
					Income tax expense (Note 9)	(593)	(483)
					Earnings	2,057		2,014
					Earnings attributable to noncontrolling interests	(28)	(22)
					Earnings attributable to controlling interests	2,029		1,992
					Preference share dividends	(102)	(92)
					Earnings attributable to common shareholders	1,927		1,900
					Earnings per common share attributable to common shareholders (Note 5)	0.95	0.94
					Diluted earnings per common share attributable to common shareholders (Note 5)	0.95	0.94
					The accompanying notes are an integral part of these interim consolidated financial statements.
						1

ENBRIDGE INC.
	CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
		Three months ended
			March 31,
			2022	2021

	(unaudited; mil ions of Canadian dol ars)

	Earnings		2,057		2,014
	Other comprehensive income/(loss), net of tax
	Change in unrealized gain on cash flow hedges		294	370
	Change in unrealized gain on net investment hedges		133	93
	Other comprehensive loss from equity investees		—	(22)
	Excluded components of fair value hedges		(1)	(1)
	Reclassification to earnings of loss on cash flow hedges		57	52
	Reclassification to earnings of pension and other postretirement benefits
	(OPEB) amounts		(2)	5
	Foreign currency translation adjustments		(708)	(796)
	Other comprehensive loss, net of tax		(227)	(299)
	Comprehensive income		1,830		1,715
	Comprehensive (income)/loss attributable to noncontrol ing interests		(13)	3
	Comprehensive income attributable to control ing interests		1,817		1,718
	Preference share dividends		(102)	(92)
	Comprehensive income attributable to common shareholders		1,715		1,626
	The accompanying notes are an integral part of these interim consolidated financial statements.
						2

ENBRIDGE INC.
	CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
		Three months ended
		March 31,
		2022		2021

			(unaudited; mil ions of Canadian dol ars, except per share amounts)
			Preference shares
	Balance at beginning of period		7,747		7,747
	Redemption of preference shares		(737)		—
			Balance at end of period		7,010		7,747
			Common shares
	Balance at beginning of period		64,799		64,768
	Shares issued on exercise of stock options				36	4
	Share purchases at stated value				(30)	—
	Other				(4)	—
			Balance at end of period		64,801		64,772
			Additional paid-in capital
	Balance at beginning of period		365		277
	Stock-based compensation				13	11
	Options exercised				(34)	(3)
	Change in reciprocal interest				—	39
	Other				(28)	—
			Balance at end of period		316		324
			Deficit
	Balance at beginning of period	(10,989)		(9,995)
	Earnings attributable to control ing interests		2,029		1,992
	Preference share dividends		(102)		(92)
	Dividends paid to reciprocal shareholder				—	3
	Share purchases in excess of stated value				(20)	—
	Other				—	(1)
			Balance at end of period		(9,082)		(8,093)
			Accumulated other comprehensive loss (Note 7)
	Balance at beginning of period		(1,096)		(1,401)
	Other comprehensive loss attributable to common shareholders, net of tax		(212)		(274)
			Balance at end of period		(1,308)		(1,675)
			Reciprocal shareholding
	Balance at beginning of period				—	(29)
	Change in reciprocal interest				—	12
			Balance at end of period				—	(17)
			Total Enbridge Inc. shareholders’ equity		61,737		63,058
			Noncontrol ing interests
	Balance at beginning of period		2,542		2,996
	Earnings attributable to noncontrol ing interests				28	22
	Other comprehensive income/(loss) attributable to noncontrol ing interests, net of tax
	Change in unrealized gain/(loss) on cash flow hedges				2	(3)
	Foreign currency translation adjustments				(17)	(22)
					(15)	(25)

	Comprehensive income/(loss) attributable to noncontrol ing interests				13	(3)
	Distributions				(60)	(66)
	Contributions				6	3
	Other				35	—
			Balance at end of period		2,536		2,930
			Total equity		64,273		65,988
			Dividends paid per common share		0.860		0.835
			The accompanying notes are an integral part of these interim consolidated financial statements.
						3

ENBRIDGE INC.
	CONSOLIDATED STATEMENTS OF CASH FLOWS
		Three months ended
			March 31,
					2022		2021
				(unaudited; mil ions of Canadian dol ars)
				Operating activities
				Earnings		2,057			2,014
				Adjustments to reconcile earnings to net cash provided by operating activities:
				Depreciation and amortization		1,055			932
				Deferred income tax expense		423		369
				Unrealized derivative fair value gain, net (Note 8)		(369)		(315)
				Income from equity investments		(491)		(395)
				Distributions from equity investments		394		388
				(Gain)/loss on dispositions		2		(41)
				Other		120		30
				Changes in operating assets and liabilities		(252)		(418)
				Net cash provided by operating activities		2,939			2,564
				Investing activities
				Capital expenditures		(1,048)			(2,059)
				Long-term investments and restricted long-term investments		(314)		(61)
				Distributions from equity investments in excess of cumulative earnings		97		61
				Additions to intangible assets		(53)		(65)
				Proceeds from disposition		—		122
				Affiliate loans, net		—		44
				Net cash used in investing activities		(1,318)			(1,958)
				Financing activities
				Net change in short-term borrowings		89		(27)
				Net change in commercial paper and credit facility draws		(283)		1,727
				Debenture and term note issues, net of issue costs		2,643			629
				Debenture and term note repayments		(1,155)			(912)
				Contributions from noncontrol ing interests		6		3
				Distributions to noncontrol ing interests		(60)		(66)
				Common shares issued		2		—
				Common shares repurchased		(50)		—
				Preference share dividends		(91)		(92)
				Common share dividends		(1,742)			(1,691)
				Redemption of preferred shares held by subsidiary		—		(115)
				Redemption of preference shares		(750)		—
				Other		(92)		(21)
				Net cash used in financing activities		(1,483)			(565)
				Effect of translation of foreign denominated cash and cash equivalents and
				restricted cash		(4)		(7)
				Net increase in cash and cash equivalents and restricted cash		134		34
				Cash and cash equivalents and restricted cash at beginning of period		320		490
				Cash and cash equivalents and restricted cash at end of period		454		524
				The accompanying notes are an integral part of these interim consolidated financial statements.
							4

ENBRIDGE INC.
	CONSOLIDATED STATEMENTS OF FINANCIAL POSITION
		March 31,		December 31,
			2022		2021
						(unaudited; mil ions of Canadian dol ars; number of shares in mil ions)
						Assets
						Current assets
	Cash and cash equivalents						413	286
	Restricted cash						41	34
	Accounts receivable and other						8,408		6,862
	Accounts receivable from affiliates						220	107
	Inventory						1,212		1,670
							10,294		8,959
						Property, plant and equipment, net	99,346		100,067
						Long-term investments	13,361		13,324
						Restricted long-term investments	594	630
						Deferred amounts and other assets	9,123		8,613
						Intangible assets, net	3,895		4,008
						Goodwil	32,503		32,775
						Deferred income taxes	275	488
						Total assets	169,391		168,864
						Liabilities and equity
						Current liabilities
	Short-term borrowings						1,604		1,515
	Accounts payable and other						8,512		9,767
	Accounts payable to affiliates						112	90
	Interest payable						605	693
	Current portion of long-term debt						4,379		6,164
							15,212		18,229
						Long-term debt	70,490		67,961
						Other long-term liabilities	7,431		7,617
						Deferred income taxes	11,985		11,689
							105,118		105,496
						Contingencies (Note 11)Equity

	Share capital
	Preference shares						7,010		7,747
	Common shares (2,026 outstanding at March 31, 2022 and December 31,
	2021)						64,801		64,799
	Additional paid-in capital						316	365
	Deficit						(9,082)		(10,989)
	Accumulated other comprehensive loss (Note 7)						(1,308)		(1,096)
	Total Enbridge Inc. shareholders' equity						61,737		60,826
	Noncontrol ing interests						2,536		2,542
							64,273		63,368
						Total liabilities and equity	169,391		168,864
						The accompanying notes are an integral part of these interim consolidated financial statements.
							5

NOTES TO THE INTERIM CONSOLIDATED FINANCIAL STATEMENTS
	(unaudited)
1. BASIS OF PRESENTATION
The accompanying unaudited interim consolidated financial statements of Enbridge Inc. ("we", "our", "us" and "Enbridge") have been prepared in accordance with general y accepted accounting principles in the United States of America (US GAAP) and Regulation S-X for interim consolidated financial information. They do not include al of the information and notes required by US GAAP for annual consolidated financial statements and should therefore be read in conjunction with our audited consolidated financial statements and notes for the year ended December 31, 2021. In the opinion of management, the interim consolidated financial statements contain al normal recurring adjustments necessary to present fairly our financial position, results of operations and cash flows for the interim periods reported. These interim consolidated financial statements fol ow the same significant accounting policies as those included in our audited consolidated financial statements for the year ended December 31, 2021, except for the adoption of new standards (Note 2). Amounts are stated in Canadian dol ars unless otherwise noted.
Our operations and earnings for interim periods can be affected by seasonal fluctuations within the gas distribution utility businesses, as wel as other factors such as supply of and demand for crude oil and natural gas, and may not be indicative of annual results.
Certain comparative figures in our interim consolidated financial statements have been reclassified to conform to the current year's presentation.
2. CHANGES IN ACCOUNTING POLICIES
ADOPTION OF NEW ACCOUNTING STANDARDSDisclosures About Government AssistanceEffective January 1, 2022, we adopted Accounting Standards Update (ASU) 2021-10 on a prospective basis. The new standard was issued in November 2021 to increase the transparency of government assistance to business entities. The ASU adds new disclosure requirements for transactions with governments that are accounted for using a grant or contribution accounting model by analogy. The required disclosures include information about the nature of transactions, accounting policy applied, impacted financial statement line items and significant terms and conditions. The adoption of this ASU did not have a material impact on our consolidated financial statements.
Accounting for Certain Lessor Leases with Variable Lease PaymentsEffective January 1, 2022, we adopted ASU 2021-05 on a prospective basis. The new standard was issued in July 2021 to amend lessor accounting for certain leases with variable lease payments that do not depend on a reference index or a rate and would have resulted in the recognition of a loss at lease commencement if classified as a sales-type or a direct financing lease. The ASU amends the classification requirements of such leases for lessors to result in an operating lease classification. The adoption of this ASU did not have a material impact on our consolidated financial statements.
Accounting for Modifications or Exchanges of Certain Equity-Classified ContractsEffective January 1, 2022, we adopted ASU 2021-04 on a prospective basis. The new standard was issued in May 2021 to clarify issuer accounting for modifications or exchanges of freestanding equity-classified written cal options that remain equity classified after modification or exchange. The ASU requires an issuer to determine the accounting for the modification or exchange based on the economic substance of the modification or exchange. The adoption of this ASU did not have a material impact on our consolidated financial statements.
		6

Accounting for Convertible Instruments and Contracts in an Entity’s Own EquityEffective January 1, 2022, we adopted ASU 2020-06 on a modified retrospective basis. The new standard was issued in August 2020 to simplify accounting for certain financial instruments. The ASU eliminates the current models that require separation of beneficial conversion and cash conversion features from convertible instruments and simplifies the derivative scope exception guidance pertaining to equity classification of contracts in an entity’s own equity. The ASU also introduces additional disclosures for convertible debt and freestanding instruments that are indexed to and settled in an entity’s own equity. The ASU amends the diluted earnings per share guidance, including the requirement to use if-converted method for al convertible instruments and an update for instruments that can be settled in either cash or shares. The adoption of this ASU did not have a material impact on our consolidated financial statements.
3. REVENUE
REVENUE FROM CONTRACTS WITH CUSTOMERSMajor Products and Services
		Gas		Gas
			Transmission		Distribution	Renewable
	Liquids	and		and		Power	Energy	Eliminations	Three months endedMarch 31, 2022(mil ions of Canadian dol ars)
	Pipelines		Midstream	Storage		Generation	Services	and Other Consolidated

Transportation revenue		2,685	1,194		251					—	—	—	4,130
Storage and other revenue		51	84		47					—	—	—	182
Gas gathering and processing
revenue		—	15		—					—	—	—	15
Gas distribution revenue		—	—		2,098					—	—	—	2,098
Electricity and transmission
		—	—		—					62	—	—	62
revenue
Total revenue from contracts with
customers		2,736	1,293		2,396					62	—	—	6,487
Commodity sales		—	—		—					—	8,325	—	8,325
Other revenue1,2		178	7		4					94	2	—	285
Intersegment revenue		141	—		11					—	10	(162)	—
Total revenue		3,055	1,300		2,411					156	8,337	(162)		15,097
		Gas		Gas
			Transmission		Distribution	Renewable
	Liquids	and		and		Power	Energy	Eliminations	Three months endedMarch 31, 2021(mil ions of Canadian dol ars)
	Pipelines		Midstream	Storage		Generation	Services	and Other Consolidated

Transportation revenue		2,329	1,121		216					—	—	—	3,666
Storage and other revenue		26	74		58					—	—	—	158
Gas gathering and processing
revenue		—	7		—					—	—	—	7
Gas distribution revenue		—	—		1,534					—	—	—	1,534
Electricity and transmission
revenue		—	—		—					26	—	—	26
Total revenue from contracts with
customers		2,355	1,202		1,808					26	—	—	5,391
Commodity sales		—	—		—					—	6,429	—	6,429
Other revenue1,2		212	12		6					91	—	(4)	317
Intersegment revenue		132	—		9					—	4	(145)	—
Total revenue		2,699	1,214		1,823					117	6,433	(149)		12,137
1 Includes mark-to-market gains from our hedging program for the three months ended March 31, 2022 and 2021 of $94 mil ion and
$130 mil ion, respectively.
2 Includes revenues from lease contracts for the three months ended March 31, 2022 and 2021 of $164 mil ion and $159 mil ion,
respectively.
					7

We disaggregate revenue into categories which represent our principal performance obligations within each business segment. These revenue categories represent the most significant revenue streams in each segment and consequently are considered to be the most relevant revenue information for management to consider in evaluating performance.
Contract Balances
	Contract	Contract	Contract
	Receivables	Assets	Liabilities
(mil ions of Canadian dol ars)Balance as at March 31, 2022
					2,784	216	1,913
Balance as at December 31, 2021					2,369	213	1,898
Contract receivables represent the amount of receivables derived from contracts with customers.
Contract assets represent the amount of revenue which has been recognized in advance of payments received for performance obligations we have fulfil ed (or partial y fulfil ed) and prior to the point in time at which our right to the payment is unconditional. Amounts included in contract assets are transferred to accounts receivable when our right to the consideration becomes unconditional.
Contract liabilities represent payments received for performance obligations which have not been fulfil ed. Contract liabilities primarily relate to make-up rights and deferred revenue. Revenue recognized during the three months ended March 31, 2022 included in contract liabilities at the beginning of the period is $61 mil ion. Increases in contract liabilities from cash received, net of amounts recognized as revenue during the three months ended March 31, 2022 were $97 mil ion.
Performance ObligationsThere was no material revenue recognized in the three months ended March 31, 2022 from performance obligations satisfied in previous periods.
Revenue to be Recognized from Unfulfilled Performance ObligationsTotal revenue from performance obligations expected to be fulfil ed in future periods is $58.3 bil ion, of which $5.5 bil ion and $6.1 bil ion are expected to be recognized during the remaining nine months ending December 31, 2022 and year ending December 31, 2023, respectively.
The revenues excluded from the amounts above based on optional exemptions available under Accounting Standards Codification (ASC) 606, as explained below, represent a significant portion of our overal revenues and revenues from contracts with customers. Certain revenues such as flow-through operating costs charged to shippers are recognized at the amount for which we have the right to invoice our customers and are excluded from the amounts for revenue to be recognized in the future from unfulfil ed performance obligations above. Variable consideration is excluded from the amounts above due to the uncertainty of the associated consideration, which is general y resolved when actual volumes and prices are determined. For example, we consider interruptible transportation service revenues to be variable revenues since volumes cannot be estimated. Additional y, the effect of escalation on certain tol s which are contractual y escalated for inflation has not been reflected in the amounts above as it is not possible to reliably estimate future inflation rates. Revenues for periods extending beyond the current rate settlement term for regulated contracts where the tol s are periodical y reset by the regulator are excluded from the amounts above since future tol s remain unknown. Final y, revenues from contracts with customers which have an original expected duration of one year or less are excluded from the amounts above.
				8

Variable ConsiderationDuring the three months ended March 31, 2022, revenue for the Canadian Mainline has been recognized in accordance with the terms of the Competitive Tol ing Settlement, which expired on June 30, 2021. The tol s in place on June 30, 2021 continue on an interim basis until a new commercial arrangement is implemented and are subject to finalization and adjustment applicable to the interim period, if any. Due to the uncertainty of adjustment to tol ing pursuant to a Canada Energy Regulator decision and potential customer negotiations, interim tol revenue recognized during the three months ended March 31, 2022 is considered variable consideration.
Recognition and Measurement of Revenues
		Gas
			Transmission	Gas		Renewable
	Liquids	and			Distribution	Power	Three months endedMarch 31, 2022(mil ions of Canadian dol ars)
	Pipelines		Midstream		and Storage	Generation Consolidated

Revenue from products transferred at a point in time								—	—	16	—	16
Revenue from products and services transferred over
time1								2,736	1,293	2,380	62	6,471
Total revenue from contracts with customers								2,736	1,293	2,396	62	6,487
		Gas
			Transmission	Gas		Renewable
	Liquids	and			Distribution	Power	Three months endedMarch 31, 2021(mil ions of Canadian dol ars)Revenue from products transferred at a point in time
	Pipelines		Midstream		and Storage	Generation Consolidated
								—	—	17	—	17
Revenue from products and services transferred over
time1								2,355	1,202	1,791	26	5,374
Total revenue from contracts with customers								2,355	1,202	1,808	26	5,391
1 Revenue from crude oil and natural gas pipeline transportation, storage, natural gas gathering, compression and treating, natural
gas distribution, natural gas storage services and electricity sales.
	9

4. SEGMENTED INFORMATION
		Gas		Gas
			Transmission		Distribution	Renewable
	Liquids	and		and		Power	Energy	Eliminations	Three months endedMarch 31, 2022(mil ions of Canadian dol ars)
	Pipelines		Midstream	Storage		Generation	Services	and Other Consolidated

Operating revenues		3,055	1,300		2,411							156	8,337		(162)			15,097
Commodity and gas distribution
costs		(11)	—		(1,468)							(4) (8,427)	163			(9,747)
Operating and administrative		(947)	(530)		(299)							(48)	(14)		(37)			(1,875)
Income from equity investments		215	221		—							55	—		—	491
Other income		17	23		21			3	3		391	458
Earnings/(loss) before interest,
income taxes, and depreciation and amortization
		2,329	1,014		665							162	(101)		355	4,424
Depreciation and amortization												(1,055)
Interest expense												(719)
Income tax expense												(593)
Earnings										2,057
Capital expenditures1		545	229		266			6	—		12	1,058
		Gas		Gas
			Transmission		Distribution	Renewable
	Liquids	and		and		Power	Energy	Eliminations	Three months endedMarch 31, 2021(mil ions of Canadian dol ars)
	Pipelines		Midstream	Storage		Generation	Services	and Other Consolidated

Operating revenues		2,699	1,214		1,823							117	6,433		(149)			12,137
Commodity and gas distribution
costs		(3)	—		(958)							— (6,353)	166			(7,148)
Operating and administrative		(819)	(434)		(272)							(43)	(14)		23			(1,559)
Income from equity investments		154	182		22							37	—		—	395
Other income/(expense)			8	11		19							45	(2)		180	261
Earnings before interest, income
taxes, and depreciation and amortization
		2,039	973		634							156	64		220	4,086
Depreciation and amortization										(932)
Interest expense										(657)

Income tax expense										(483)

Earnings												2,014
Capital expenditures1		1,195	482		219			5	—		12	1,913
1 Includes al owance for equity funds used during construction.
					10

5. EARNINGS PER COMMON SHARE AND DIVIDENDS PER SHARE
BASICEarnings per common share is calculated by dividing earnings attributable to common shareholders by the weighted average number of common shares outstanding. On December 30, 2021, we closed the sale of our minority ownership of Noverco Inc. (Noverco). For the three months ended March 31, 2021, the weighted average number of common shares outstanding was reduced by our pro-rata weighted average interest in our own common shares of approximately 3 mil ion, resulting from our reciprocal investment in Noverco.
DILUTEDThe treasury stock method is used to determine the dilutive impact of stock options. This method assumes any proceeds from the exercise of stock options would be used to purchase common shares at the average market price during the period.
Weighted average shares outstanding used to calculate basic and diluted earnings per share are as fol ows:
	Three months ended
		March 31,
		2022	2021
(number of shares in mil ions)
Weighted average shares outstanding		2,026		2,022
Effect of dilutive options		3	1
Diluted weighted average shares outstanding		2,029		2,023
For the three months ended March 31, 2022 and 2021, 12.9 mil ion and 27.6 mil ion, respectively, of anti-dilutive stock options with a weighted average exercise price of $56.09 and $51.42, respectively, were excluded from the diluted earnings per common share calculation.
				11

DIVIDENDS PER SHAREOn May 3, 2022, our Board of Directors declared the fol owing quarterly dividends. Al dividends are payable on June 1, 2022 to shareholders of record on May 13, 2022.
	Dividend per share
Common Shares1		$0.86000
Preference Shares, Series A		$0.34375
Preference Shares, Series B		$0.21340
Preference Shares, Series C2		$0.18400
Preference Shares, Series D		$0.27875
Preference Shares, Series F		$0.29306
Preference Shares, Series H		$0.27350
Preference Shares, Series J3		US$0.30540
Preference Shares, Series L		US$0.30993
Preference Shares, Series N		$0.31788
Preference Shares, Series P		$0.27369
Preference Shares, Series R		$0.25456
Preference Shares, Series 1		US$0.37182
Preference Shares, Series 3		$0.23356
Preference Shares, Series 5		US$0.33596
Preference Shares, Series 7		$0.27806
Preference Shares, Series 9		$0.25606
Preference Shares, Series 11		$0.24613
Preference Shares, Series 13		$0.19019
Preference Shares, Series 15		$0.18644
Preference Shares, Series 19		$0.30625
1 The quarterly dividend per common share was increased 3% to $0.86 from $0.835, effective March 1, 2022.2 The quarterly dividend per share paid on Series C was increased to $0.18400 from $0.15719 on March 1, 2022, due to reset on a
quarterly basis fol owing the date of issuance of the Series C Preference Shares.
3 On May 2, 2022, we notified holders of our outstanding Cumulative Redeemable Preference Shares, Series J (Series J Shares)
(TSX: ENB.PR.U) of our intention to redeem al US$200 mil ion outstanding Series J Shares on June 1, 2022.
6. DEBT
CREDIT FACILITIESThe fol owing table provides details of our committed credit facilities as at March 31, 2022:
				Total
			Maturity1	Facilities	Draws2	Available
(mil ions of Canadian dol ars)
Enbridge Inc.			2022 - 2026	7,616	7,012				604
Enbridge (U.S.) Inc.			2023 - 2026	6,870	5,351	1,519
Enbridge Pipelines Inc.			2023	3,000	627	2,373
Enbridge Gas Inc.			2023	2,000	1,604				396
Total committed credit facilities						19,486	14,594	4,892
	1 Maturity date is inclusive of the one-year term out option for certain credit facilities.2 Includes facility draws and commercial paper issuances that are back-stopped by credit facilities.
On February 10, 2022, we renewed our three year $1.0 bil ion sustainability-linked credit facility, extending the maturity date out to July 2025.
In addition to the committed credit facilities noted above, we maintain $1.3 bil ion of uncommitted demand letter of credit facilities, of which $947 mil ion was unutilized as at March 31, 2022. As at December 31, 2021, we had $1.3 bil ion of uncommitted demand letter of credit facilities, of which $854 mil ion was unutilized.
								12

Our credit facilities carry a weighted average standby fee of 0.1% per annum on the unused portion and draws bear interest at market rates. Certain credit facilities serve as a back-stop to the commercial paper programs and we have the option to extend such facilities, which are currently scheduled to mature from 2022 to 2026.
As at March 31, 2022 and December 31, 2021, commercial paper and credit facility draws, net of short-term borrowings and non-revolving credit facilities that mature within one year, of $12.4 bil ion and $11.3 bil ion, respectively, were supported by the availability of long-term committed credit facilities and, therefore, have been classified as long-term debt.
LONG-TERM DEBT ISSUANCESDuring the three months ended March 31, 2022, we completed the fol owing long-term debt issuances totaling US$1.5 bil ion and $750 mil ion:
		Principal
Company	Issue Date	Amount
(mil ions of Canadian dol ars unless otherwise stated)Enbridge Inc.
	January 2022		5.00% hybrid fixed-to-fixed subordinated notes due January 2082	$750
	February 2022		Floating rate senior notes due February 20241	US$600
	February 2022		2.15% senior notes due February 2024	US$400
	February 2022		2.50% senior notes due February 2025	US$500
1 Notes carry an interest rate set to equal Secured Overnight Financing Rate plus a margin of 63 basis points.
LONG-TERM DEBT REPAYMENTSDuring the three months ended March 31, 2022, we completed the fol owing long-term debt repayments totaling $200 mil ion and US$750 mil ion:
		Principal
Company	Repayment Date	Amount
(mil ions of Canadian dol ars unless otherwise stated)Enbridge Inc.
	February 2022		Floating rate notes1	US$750
	February 2022		4.85% medium-term notes	$200
1 Notes carried an interest rate set to equal the three-month London Interbank Offered Rate plus a margin of 50 basis points.
SUBORDINATED TERM NOTESAs at March 31, 2022 and December 31, 2021, our fixed-to-floating rate and fixed-to-fixed rate subordinated term notes had a principal value of $8.4 bil ion and $7.7 bil ion, respectively.
FAIR VALUE ADJUSTMENTAs at March 31, 2022 and December 31, 2021, the net fair value adjustments to total debt assumed in a historical acquisition were $646 mil ion and $667 mil ion, respectively. During the three months ended March 31, 2022 and 2021, amortization of the fair value adjustment recorded as a reduction to Interest expense in the Consolidated Statements of Earnings was $11 mil ion and $12 mil ion, respectively.
DEBT COVENANTSOur credit facility agreements and term debt indentures include standard events of default and covenant provisions whereby accelerated repayment and/or termination of the agreements may result if we were to default on payment or violate certain covenants. As at March 31, 2022, we were in compliance with al covenant provisions.
				13

7. COMPONENTS OF ACCUMULATED OTHER COMPREHENSIVE LOSS
Changes in Accumulated other comprehensive loss (AOCI) attributable to our common shareholders for the three months ended March 31, 2022 and 2021 are as fol ows:
		Excluded				Pension
	Cash	Components	Net	Cumulative			and
	Flow	of Fair Value		Investment	Translation		Equity	OPEB
	Hedges	Hedges	Hedges	Adjustment		Investees	Adjustment	Total
(mil ions of Canadian dol ars)
Balance as at January 1, 2022		(897)			—	(166)				56	(5)	(84) (1,096)
Other comprehensive income/(loss)
retained in AOCI		384			(1)	133				(691)	—	—	(175)
Other comprehensive loss/(income)
reclassified to earningsInterest rate contracts1
		76			—	—				—	—	—	76
Commodity contracts2		—			—	—				—	—	—	—
Foreign exchange contracts3		(4)			—	—				—	—	—	(4)
Other contracts4		2			—	—				—	—	—	2
Amortization of pension and OPEB
									actuarial gain5	—			—	—			—	—			(3)	(3)
		458			(1)	133				(691)	—				(3)	(104)
Tax impact
Income tax on amounts retained in
									AOCI	(92)			—	—			—	—	—	(92)
Income tax on amounts reclassified to
									earnings	(17)			—	—			—	—			1	(16)
		(109)			—	—				—	—				1	(108)
Balance as at March 31, 2022		(548)			(1)	(33)				(635)	(5)	(86) (1,308)
		Excluded				Pension
	Cash	Components	Net	Cumulative			and
	Flow	of Fair Value		Investment	Translation		Equity	OPEB
	Hedges	Hedges	Hedges	Adjustment		Investees	Adjustment	Total
(mil ions of Canadian dol ars)Balance as at January 1, 2021
		(1,326)			5	(215)				568	66	(499) (1,401)
Other comprehensive income/(loss)
retained in AOCI		493			(1)	105				(774)	(26)	—	(203)
Other comprehensive loss/(income)
reclassified to earningsInterest rate contracts1
		63			—	—				—	—	—	63
Commodity contracts2		1			—	—				—	—	—	1
Foreign exchange contracts3		1			—	—				—	—	—	1
Amortization of pension and OPEB
									actuarial loss5	—			—	—			—	—			7	7
Other		17			—	—				(20)	3	—	—
		575			(1)	105				(794)	(23)				7	(131)
Tax impact
Income tax on amounts retained in
									AOCI	(120)			—	(12)			—	4	—	(128)
Income tax on amounts reclassified to
									earnings	(13)			—	—			—	—			(2)	(15)
		(133)			—	(12)				—	4				(2)	(143)
Balance as at March 31, 2021		(884)			4	(122)				(226)	47	(494) (1,675)
	1 Reported within Interest expense in the Consolidated Statements of Earnings.2 Reported within Transportation and other services revenues, Commodity sales revenue, Commodity costs and Operating and
administrative expense in the Consolidated Statements of Earnings.
3 Reported within Transportation and other services revenues and Net foreign currency gain in the Consolidated Statements of
Earnings.
4 Reported within Operating and administrative expense in the Consolidated Statements of Earnings.5 These components are included in the computation of net periodic benefit costs and are reported within Other income in the
Consolidated Statements of Earnings.
		14

8. RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
MARKET RISKOur earnings, cash flows and other comprehensive income/(loss) (OCI) are subject to movements in foreign exchange rates, interest rates, commodity prices and our share price (col ectively, market risks). Formal risk management policies, processes and systems have been designed to mitigate these risks.
The fol owing summarizes the types of market risks to which we are exposed and the risk management instruments used to mitigate them. We use a combination of qualifying and non-qualifying derivative instruments to manage the risks noted below.
Foreign Exchange RiskWe generate certain revenues, incur expenses, and hold a number of investments and subsidiaries that are denominated in currencies other than Canadian dol ars. As a result, our earnings, cash flows and OCI are exposed to fluctuations resulting from foreign exchange rate variability.
We employ financial derivative instruments to hedge foreign currency denominated earnings exposure. A combination of qualifying cash flow, fair value and non-qualifying derivative instruments is used to hedge anticipated foreign currency denominated revenues and expenses, and to manage variability in cash flows. We hedge certain net investments in United States (US) dol ar denominated investments and subsidiaries using US dol ar denominated debt.
Interest Rate RiskOur earnings and cash flows are exposed to short-term interest rate variability due to the regular repricing of our variable rate debt, primarily commercial paper. We monitor our debt portfolio mix of fixed and variable rate debt instruments to manage a consolidated portfolio of floating rate debt within the Board of Directors approved policy limit of a maximum of 30% of floating rate debt as a percentage of total debt outstanding. We primarily use qualifying derivative instruments to manage interest rate risk. Pay fixed-receive floating interest rate swaps may be used to hedge against the effect of future interest rate movements. We have implemented a program to mitigate the impact of short-term interest rate volatility on interest expense via execution of floating to fixed interest rate swaps with an average swap rate of 2.1%.
We are exposed to changes in the fair value of fixed rate debt that arise as a result of the changes in market interest rates. Pay floating-receive fixed interest rate swaps are used, when applicable, to hedge against future changes to the fair value of fixed rate debt which mitigates the impact of fluctuations in the fair value of fixed rate debt via execution of fixed to floating interest rate swaps. As at March 31, 2022, we do not have any pay floating-receive fixed interest rate swaps outstanding.
Our earnings and cash flows are also exposed to variability in longer term interest rates ahead of anticipated fixed rate term debt issuances. Forward starting interest rate swaps are used to hedge against the effect of future interest rate movements. We have established a program including some of our subsidiaries to mitigate our exposure to long-term interest rate variability on select forecast term debt issuances via execution of floating to fixed interest rate swaps with an average swap rate of 2.1%.
Commodity Price RiskOur earnings and cash flows are exposed to changes in commodity prices as a result of our ownership interests in certain assets and investments, as wel as through the activities of our energy services subsidiaries. These commodities include natural gas, crude oil, power and NGL. We employ financial and physical derivative instruments to fix a portion of the variable price exposures that arise from physical transactions involving these commodities. We use primarily non-qualifying derivative instruments to manage commodity price risk.
	15

Equity Price RiskEquity price risk is the risk of earnings fluctuations due to changes in our share price. We have exposure to our own common share price through the issuance of various forms of stock-based compensation, which affect earnings through revaluation of the outstanding units every period. We use equity derivatives to manage the earnings volatility derived from one form of stock-based compensation, restricted share units. We use a combination of qualifying and non-qualifying derivative instruments to manage equity price risk.
TOTAL DERIVATIVE INSTRUMENTSWe general y have a policy of entering into individual International Swaps and Derivatives Association, Inc. agreements, or other similar derivative agreements, with the majority of our financial derivative counterparties. These agreements provide for the net settlement of derivative instruments outstanding with specific counterparties in the event of bankruptcy or other significant credit events, and reduce our credit risk exposure on financial derivative asset positions outstanding with the counterparties in those circumstances.
The fol owing table summarizes the Consolidated Statements of Financial Position location and carrying value of our derivative instruments, as wel as the maximum potential settlement amounts in the event of the specific circumstances described above. Al amounts are presented gross in the Consolidated Statements of Financial Position.
	Derivative	Derivative
	Instruments	Instruments	Non-		Total Gross
	Used as	Used as	QualifyingDerivative		Derivative	Amounts	Total Net
	Cash Flow	Fair Value			Instruments	Available	Derivative
March 31, 2022	Hedges	Hedges		Instruments	as Presented	for Offset	Instruments
(mil ions of Canadian dol ars)Accounts receivable and other
Foreign exchange contracts								—	—	342			342	(52)	290
Interest rate contracts								149	—	—			149	—	149
Commodity contracts								—	—	274			274	(186)					88
Other contracts								3	—	7			10	—	10
								152	—	623			775	(238)	537
Deferred amounts and other assets
Foreign exchange contracts								—	—	470			470	(142)	328
Interest rate contracts								283	—	—			283	—	283
Commodity contracts								—	—	56			56	(23)					33
Other contracts								3	—	2		5		—	5
								286	—	528			814	(165)	649
Accounts payable and other
Foreign exchange contracts								—	—	(187)			(187)	52	(135)
Interest rate contracts								(28)	—	(23)			(51)	—	(51)
Commodity contracts								(14)	—	(381)			(395)	186	(209)
								(42)	—	(591)			(633)	238	(395)
Other long-term liabilities
Foreign exchange contracts								—			(37)	(292)				(329)	142	(187)
Interest rate contracts								(4)	—	—			(4)	—	(4)
Commodity contracts								(13)	—	(96)			(109)	23	(86)
								(17)			(37)	(388)				(442)	165	(277)
Total net derivative assets/(liabilities)
Foreign exchange contracts								—			(37)	333				296	—	296
Interest rate contracts								400	—	(23)			377	—	377
Commodity contracts								(27)	—	(147)			(174)	—	(174)
Other contracts								6	—	9			15	—	15
								379			(37)	172				514	—	514
		16

	Derivative	Derivative
	Instruments	Instruments	Non-		Total Gross
	Used as	Used as	QualifyingDerivative		Derivative	Amounts	Total Net
	Cash Flow	Fair Value			Instruments	Available	Derivative
December 31, 2021	Hedges	Hedges		Instruments	as Presented	for Offset	Instruments
(mil ions of Canadian dol ars)Accounts receivable and other
Foreign exchange contracts								—	—	259					259	(41)	218
Interest rate contracts								64	—	—					64	—	64
Commodity contracts								—	—	204					204	(129)		75
Other contracts								—	—	2					2	—	2
								64	—	465					529	(170)	359
Deferred amounts and other assets
Foreign exchange contracts								—	—	240					240	(61)	179
Interest rate contracts								88	—	—					88	(1)	87
Commodity contracts								—	—	29					29	(13)		16
Other contracts								—	—	3					3	—	3
								88	—	272					360	(75)	285
Accounts payable and other
Foreign exchange contracts								(15)	(112)	(176)					(303)	41	(262)
Interest rate contracts		(150)			—	—						(150)	—	(150)
Commodity contracts								(14)	—	(250)					(264)	129	(135)
		(179)	(112)	(426)						(717)	170	(547)
Other long-term liabilities
Foreign exchange contracts								—	—	(423)					(423)	61	(362)
Interest rate contracts								(1)	—	(23)					(24)	1	(23)
Commodity contracts								(17)	—	(67)					(84)	13	(71)
								(18)	—	(513)					(531)	75	(456)
Total net derivative assets/(liabilities)
Foreign exchange contracts								(15)	(112)	(100)					(227)	—	(227)
Interest rate contracts								1	—	(23)					(22)	—	(22)
Commodity contracts								(31)	—	(84)					(115)	—	(115)
Other contracts								—	—	5					5	—	5
								(45)	(112)	(202)					(359)	—	(359)
The fol owing table summarizes the maturity and notional principal or quantity outstanding related to our derivative instruments.
March 31, 2022		2022		2023	2024		2025				2026 Thereafter	Total
Foreign exchange contracts - US dol ar forwards -
purchase (mil ions of US dol ars)			848		— 1,000	500	—	— 2,348
Foreign exchange contracts - US dol ar forwards - sel
(mil ions of US dol ars)		7,544 5,794 4,544 3,372 2,772								492 24,518
Foreign exchange contracts - British pound (GBP)
forwards - sel (mil ions of GBP)			21		29	30		30	28	32	170
Foreign exchange contracts - Euro forwards - sel (mil ions
of Euro)			95		92	91		86	85				343	792
Foreign exchange contracts - Japanese yen forwards -
purchase (mil ions of yen)		52,500		—	—		—	—	— 52,500
Interest rate contracts - short-term debt pay fixed rate
(mil ions of Canadian dol ars)			536		796	128		30	26	64 1,580
Interest rate contracts - long-term debt pay fixed rate
(mil ions of Canadian dol ars)		2,549 2,587 1,687			562	—	— 7,385
Equity contracts (mil ions of Canadian dol ars)			—		26	21		—	—	—	47
Commodity contracts - natural gas (bil ions of cubic feet)1			172		33	13		11	—	—	229
Commodity contracts - crude oil (mil ions of barrels)1			10		(1)	—		—	—	—	9
Commodity contracts - power (megawatt per hour) (MW/H)		(14)		(43)	(43)		(43)	—	—	(37) 2
1 Total is a net purchase/(sale) of underlying commodity.2 Total is an average net purchase/(sale) of power.
		17

Fair Value DerivativesFor foreign exchange derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative is included in Net foreign currency gain or Interest expense in the Consolidated Statements of Earnings. The offsetting loss or gain on the hedged item attributable to the hedged risk is included in Net foreign currency gain in the Consolidated Statements of Earnings. Any excluded components are included in the Consolidated Statements of Comprehensive Income.
	Three months ended
		March 31,
		2022	2021
(mil ions of Canadian dol ars)Unrealized gain/(loss) on derivative
		76	(3)
Unrealized loss on hedged item		(87)	(4)
Realized loss on derivative		(75)	(39)
Realized gain on hedged item		85	45
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive IncomeThe fol owing table presents the effect of cash flow hedges, fair value hedges and net investment hedges on our consolidated earnings and consolidated comprehensive income, before the effect of income taxes:
	Three months ended
		March 31,
		2022	2021
(mil ions of Canadian dol ars)Amount of unrealized gain/(loss) recognized in OCI
Cash flow hedges
				Foreign exchange contracts		2	(20)
				Interest rate contracts		377	497
				Commodity contracts		4	(8)
				Other contracts		3	3
Fair value hedges
				Foreign exchange contracts		(1)	(1)
		385	471
Amount of loss reclassified from AOCI to earnings
				Foreign exchange contracts1		13	1
				Interest rate contracts2		76	63
				Commodity contracts		—	1
				Other contracts3		2	—
						91	65
1 Reported within Transportation and other services revenues and Net foreign currency gain/(loss) in the Consolidated Statements
of Earnings.
2 Reported within Interest expense in the Consolidated Statements of Earnings.3 Reported within Operating and administrative expense in the Consolidated Statements of Earnings.
We estimate that a gain of $3 mil ion of AOCI related to unrealized cash flow hedges wil be reclassified to earnings in the next 12 months. Actual amounts reclassified to earnings depend on the foreign exchange rates, interest rates and commodity prices in effect when derivative contracts that are currently outstanding mature. For al forecasted transactions, the maximum term over which we are hedging exposures to the variability of cash flows is 45 months as at March 31, 2022.
					18

Non-Qualifying DerivativesThe fol owing table presents the unrealized gains and losses associated with changes in the fair value of our non-qualifying derivatives:
	Three months ended
		March 31,
		2022	2021
(mil ions of Canadian dol ars)Foreign exchange contracts1
		433	236
Interest rate contracts2		—	2
Commodity contracts3		(68)	72
Other contracts4		4	5
Total unrealized derivative fair value gain/(loss), net		369	315
1 For the respective three months ended periods, reported within Transportation and other services revenues (2022 - $134 mil ion
gain; 2021 - $154 mil ion gain) and Net foreign currency gain (2022 - $299 mil ion gain; 2021 - $82 mil ion gain) in the Consolidated Statements of Earnings.
2 Reported as an (increase)/decrease within Interest expense in the Consolidated Statements of Earnings.3 For the respective three months ended periods, reported within Transportation and other services revenues (2022 - $16 mil ion
loss; 2021 - $3 mil ion loss), Commodity sales (2022 - $16 mil ion loss; 2021 - $171 mil ion gain), Commodity costs (2022 - $37 mil ion loss; 2021 - $100 mil ion loss) and Operating and administrative expense (2022 - $1 mil ion gain; 2021 - $4 mil ion gain) in the Consolidated Statements of Earnings.
4 Reported within Operating and administrative expense in the Consolidated Statements of Earnings.
LIQUIDITY RISK
	Liquidity risk is the risk that we wil not be able to meet our financial obligations, including commitments and guarantees, as they become due. In order to mitigate this risk, we forecast cash requirements over a 12-month rol ing time period to determine whether sufficient funds wil be available and maintain substantial capacity under our committed bank lines of credit to address any contingencies. Our primary sources of liquidity and capital resources are funds generated from operations, the issuance of commercial paper and draws under committed credit facilities and long-term debt, which includes debentures and medium-term notes. We also maintain current shelf prospectuses with securities regulators which enables ready access to either the Canadian or US public capital markets, subject to market conditions. In addition, we maintain sufficient liquidity through committed credit facilities with a diversified group of banks and institutions which, if necessary, enables us to fund al anticipated requirements for approximately one year without accessing the capital markets. We are in compliance with al the terms and conditions of our committed credit facility agreements and term debt indentures as at March 31, 2022. As a result, al credit facilities are available to us and the banks are obligated to fund and have been funding us under the terms of the facilities.
CREDIT RISK
	Entering into derivative instruments may result in exposure to credit risk from the possibility that a counterparty wil default on its contractual obligations. In order to mitigate this risk, we enter into risk management transactions primarily with institutions that possess strong investment grade credit ratings. Credit risk relating to derivative counterparties is mitigated through maintenance and monitoring of credit exposure limits and contractual requirements, netting arrangements and ongoing monitoring of counterparty credit exposure using external credit rating services and other analytical tools.
				19

We have credit concentrations and credit exposure, with respect to derivative instruments, in the fol owing counterparty segments:
	March 31,		December 31,
		2022		2021
(mil ions of Canadian dol ars)Canadian financial institutions
					800	424
US financial institutions					210	130
European financial institutions					347	181
Asian financial institutions					66	30
Other1					161	122
					1,584		887
	1 Other is comprised of commodity clearing house and physical natural gas and crude oil counterparties.
As at March 31, 2022, we provided letters of credit totaling nil in lieu of providing cash col ateral to our counterparties pursuant to the terms of the relevant International Swaps and Derivatives Association agreements. We held no cash col ateral on derivative asset exposures as at March 31, 2022 and December 31, 2021.
Gross derivative balances have been presented without the effects of col ateral posted. Derivative assets are adjusted for non-performance risk of our counterparties using their credit default swap spread rates, and are reflected at fair value. For derivative liabilities, our non-performance risk is considered in the valuation.
Credit risk also arises from trade and other long-term receivables, and is mitigated through credit exposure limits and contractual requirements, assessment of credit ratings and netting arrangements. Within Enbridge Gas Inc., credit risk is mitigated by the utility's large and diversified customer base and the ability to recover an estimate for expected credit losses through the ratemaking process. We actively monitor the financial strength of large industrial customers, and in select cases, have obtained additional security to minimize the risk of default on receivables. General y, we utilize a loss al owance matrix which contemplates historical credit losses by age of receivables, adjusted for any forward-looking information and management expectations to measure lifetime expected credit losses of receivables. The maximum exposure to credit risk related to non-derivative financial assets is their carrying value.
FAIR VALUE MEASUREMENTSOur financial assets and liabilities measured at fair value on a recurring basis include derivative and other financial instruments. We also disclose the fair value of other financial instruments not measured at fair value. The fair value of financial instruments reflects our best estimates of market value based on general y accepted valuation techniques or models and is supported by observable market prices and rates. When such values are not available, we use discounted cash flow analysis from applicable yield curves based on observable market inputs to estimate fair value.
FAIR VALUE OF FINANCIAL INSTRUMENTSWe categorize our financial instruments measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement.
Level 1Level 1 includes financial instruments measured at fair value based on unadjusted quoted prices for identical assets and liabilities in active markets that are accessible at the measurement date. An active market for a financial instrument is considered to be a market where transactions occur with sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 instruments consist primarily of exchange-traded derivatives used to mitigate the risk of crude oil price fluctuations, as wel as restricted long-term investments in Canadian equity securities that are held in trust in accordance with the Canada Energy Regulator's (CER) regulatory requirements under the Land Matters Consultation Initiative (LMCI).
					20

Level 2Level 2 includes financial instrument valuations determined using directly or indirectly observable inputs other than quoted prices included within Level 1. Financial instruments in this category are valued using models or other industry standard valuation techniques derived from observable market data. Such valuation techniques include inputs such as quoted forward prices, time value, volatility factors and broker quotes that can be observed or corroborated in the market for the entire duration of the financial instrument. Derivatives valued using Level 2 inputs include non-exchange traded derivatives such as over-the-counter foreign exchange forward and cross currency swap contracts, interest rate swaps, physical forward commodity contracts, as wel as commodity swaps and options for which observable inputs can be obtained.
We have also categorized the fair value of our available-for-sale preferred share investment, long-term debt and restricted long-term investments in Canadian government bonds held in trust in accordance with the CER's regulatory requirements under the LMCI as Level 2. The fair value of our available-for-sale preferred share investment is based on the redemption value, which equals the face value plus accrued and unpaid interest periodical y reset based on market interest rates. The fair value of our long-term debt is based on quoted market prices for instruments of similar yield, credit risk and tenor. When possible, the fair value of our restricted long-term investments is based on quoted market prices for similar instruments and, if not available, based on broker quotes.
Level 3Level 3 includes derivative valuations based on inputs which are less observable, unavailable or where the observable data does not support a significant portion of the derivatives’ fair value. General y, Level 3 derivatives are longer dated transactions, occur in less active markets, occur at locations where pricing information is not available or have no binding broker quote to support Level 2 classification. We have developed methodologies, benchmarked against industry standards, to determine fair value for these derivatives based on extrapolation of observable future prices and rates. Derivatives valued using Level 3 inputs primarily include long-dated derivative power, NGL and natural gas contracts, basis swaps, commodity swaps, and power and energy swaps, as wel as physical forward commodity contracts. We do not have any other financial instruments categorized in Level 3.
We use the most observable inputs available to estimate the fair value of our derivatives. When possible, we estimate the fair value of our derivatives based on quoted market prices. If quoted market prices are not available, we use estimates from third party brokers. For non-exchange traded derivatives classified in Levels 2 and 3, we use standard valuation techniques to calculate the estimated fair value. These methods include discounted cash flows for forwards and swaps and Black-Scholes-Merton pricing models for options. Depending on the type of derivative and nature of the underlying risk, we use observable market prices (interest, foreign exchange, commodity and share price) and volatility as primary inputs to these valuation techniques. Final y, we consider our own credit default swap spread as wel as the credit default swap spreads associated with our counterparties in our estimation of fair value.
	21

We have categorized our derivative assets and liabilities measured at fair value as fol ows:
				Total Gross
				Derivative
March 31, 2022	Level 1	Level 2	Level 3	Instruments
(mil ions of Canadian dol ars)
Financial assets
Current derivative assets
					Foreign exchange contracts		—	342		—		342
					Interest rate contracts		—	149		—		149
					Commodity contracts		36	172	66			274
					Other contracts		—	10		—		10
							36	673	66			775
Long-term derivative assets
					Foreign exchange contracts		—	470		—		470
					Interest rate contracts		—	283		—		283
					Commodity contracts		—	24	32			56
					Other contracts		—	5	—		5
							—	782	32			814
Financial liabilities
Current derivative liabilities
					Foreign exchange contracts		—	(187)		—		(187)
					Interest rate contracts		—	(51)		—		(51)
					Commodity contracts		(27)	(168)	(200)			(395)
							(27)	(406)	(200)			(633)
Long-term derivative liabilities
					Foreign exchange contracts		—	(329)		—		(329)
					Interest rate contracts		—	(4)	—		(4)
					Commodity contracts		—	(31)	(78)			(109)
							—	(364)	(78)			(442)
Total net financial assets/(liabilities)
					Foreign exchange contracts		—	296		—		296
					Interest rate contracts		—	377		—		377
					Commodity contracts		9	(3)	(180)			(174)
					Other contracts		—	15		—		15
							9	685	(180)			514
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				Total Gross
				Derivative
December 31, 2021	Level 1	Level 2	Level 3	Instruments
(mil ions of Canadian dol ars)
Financial assets
Current derivative assets
Foreign exchange contracts						—	259		—			259
Interest rate contracts						—	64		—			64
Commodity contracts						38	71	95				204
Other contracts						—	2	—			2
						38	396	95				529
Long-term derivative assets
Foreign exchange contracts						—	240		—			240
Interest rate contracts						—	88		—			88
Commodity contracts						—	21		8			29
Other contracts						—	3	—			3
						—	352		8			360
Financial liabilities
Current derivative liabilities
Foreign exchange contracts						—	(303)		—			(303)
Interest rate contracts						—	(150)		—			(150)
Commodity contracts						(52)	(66)	(146)				(264)
						(52)	(519)	(146)				(717)
Long-term derivative liabilities
Foreign exchange contracts						—	(423)		—			(423)
Interest rate contracts						—	(24)		—			(24)
Commodity contracts						—	(19)	(65)				(84)
						—	(466)	(65)				(531)
Total net financial assets/(liabilities)
Foreign exchange contracts						—	(227)		—			(227)
Interest rate contracts						—	(22)		—			(22)
Commodity contracts						(14)					7	(108)		(115)
Other contracts						—	5	—			5
						(14)	(237)	(108)				(359)
The significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments were as fol ows:
						Fair	Unobservable	Minimum	Maximum	Weighted					Unit of
March 31, 2022						Value	Input	Price	Price	Average Price	Measurement
(fair value in mil ions of Canadian dol ars)Commodity contracts - financial1
Natural gas							5	Forward gas price	3.94	9.60	6.24	$/mmbtu2
Crude							(3)			Forward crude price	83.47	124.49	106.20				$/barrel
Power						(54)			Forward power price	22.33	121.08	77.14				$/MW/H
Commodity contracts - physical1
Natural gas						(97)	Forward gas price	3.48	15.02	6.23	$/mmbtu2
Crude						(31)			Forward crude price	97.55	139.67	118.41				$/barrel
						(180)
1 Financial and physical forward commodity contracts are valued using a market approach valuation technique.2 One mil ion British thermal units (mmbtu).

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If adjusted, the significant unobservable inputs disclosed in the table above would have a direct impact on the fair value of our Level 3 derivative instruments. The significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments include forward commodity prices. Changes in forward commodity prices could result in significantly different fair values for our Level 3 derivatives.
Changes in net fair value of derivative assets and liabilities classified as Level 3 in the fair value hierarchy were as fol ows:
	Three months ended
		March 31,
		2022	2021
(mil ions of Canadian dol ars)
Level 3 net derivative liability at beginning of period		(108)	(191)
Total gain/(loss)
Included in earnings1		(52)	(72)
Included in OCI		4	(5)
Settlements		(24)	149
Level 3 net derivative liability at end of period		(180)	(119)
1 Reported within Transportation and other services revenues, Commodity costs and Operating and administrative expense in the
Consolidated Statements of Earnings.
There were no transfers into or out of Level 3 as at March 31, 2022 or December 31, 2021.
NET INVESTMENT HEDGESWe currently have designated a portion of our US dol ar denominated debt, as wel as a portfolio of foreign exchange forward contracts in prior periods, as a hedge of our net investment in US dol ar denominated investments and subsidiaries.
During the three months ended March 31, 2022 and 2021, we recognized an unrealized foreign exchange gain of $133 mil ion and $105 mil ion, respectively, on the translation of US dol ar denominated debt. During the three months ended March 31, 2022 and 2021, we recognized nil on the change in fair value of our outstanding foreign exchange forward contracts in OCI and nil in OCI associated with the settlement of foreign exchange forward contracts or with the settlement of US dol ar denominated debt that had matured during the period.
FAIR VALUE OF OTHER FINANCIAL INSTRUMENTSCertain long-term investments in other entities with no actively quoted prices are classified as Fair Value Measurement Alternative (FVMA) investments and are recorded at cost less impairment. The carrying value of FVMA investments totaled $52 mil ion as at March 31, 2022 and December 31, 2021.
We have Restricted long-term investments held in trust totaling $213 mil ion and $217 mil ion as at March 31, 2022 and December 31, 2021, respectively, which are classified as Level 1 in the fair value hierarchy. We also have Restricted long-term investments held in trust totaling $381 mil ion and $413 mil ion as at March 31, 2022 and December 31, 2021, respectively, which are classified as Level 2 in the fair value hierarchy. Level 1 and Level 2 Restricted long-term investments are recognized at fair value. These securities are classified as restricted funds which are col ected from customers and held in trust for the purpose of funding pipeline abandonment in accordance with regulatory requirements. There were unrealized holding losses of $60 mil ion and $45 mil ion for the three months ended March 31, 2022 and 2021, respectively.
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As at March 31, 2022 and December 31, 2021, our long-term debt had a carrying value of $75.2 bil ion and $74.4 bil ion, respectively, before debt issuance costs and a fair value of $75.5 bil ion and $82.0 bil ion, respectively. We also have non-current notes receivable carried at book value and recorded in Deferred amounts and other assets in the Consolidated Statements of Financial Position. As at March 31, 2022 and December 31, 2021, the non-current notes receivable had a carrying value of $0.9 bil ion and $1.0 bil ion, respectively, which also approximates their fair value.
The fair value of financial assets and liabilities other than derivative instruments, long-term investments, restricted long-term investments, long-term debt and non-current notes receivable described above approximate their carrying value due to the short period to maturity.
9. INCOME TAXES
The effective income tax rates for the three months ended March 31, 2022 and 2021 were 22.4% and 19.3%, respectively. The period-over-period increase in the effective income tax rate is due to the effect of rate-regulated accounting for income taxes relative to earnings and an increase in US minimum tax.
10. PENSION AND OTHER POSTRETIREMENT BENEFITS
	Three months ended
		March 31,
		2022	2021
(mil ions of Canadian dol ars)Service cost
		45	48
Interest cost1		41	32
Expected return on plan assets1		(98)	(84)
Amortization of actuarial (gain)/loss1		(1)	14
Net periodic benefit (credit)/cost		(13)	10
1 Reported within Other income in the Consolidated Statements of Earnings.
11. CONTINGENCIES
We and our subsidiaries are involved in various legal and regulatory actions and proceedings which arise in the normal course of business, including interventions in regulatory proceedings and chal enges to regulatory approvals and permits. While the final outcome of such actions and proceedings cannot be predicted with certainty, management believes that the resolution of such actions and proceedings wil not have a material impact on our interim consolidated financial position or results of operations.
TAX MATTERSWe and our subsidiaries maintain tax liabilities related to uncertain tax positions. While ful y supportable in our view, these tax positions, if chal enged by tax authorities, may not be ful y sustained on review.
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