Enbridge (ENB) 10-Q 3 Nov 23 2023 Q3 Quarterly report Financial data

COVER

COVER - shares	9 Months Ended
	Sep. 30, 2023	Oct. 27, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
Document Transition Report	false
Entity File Number	001-15254
Entity Registrant Name	ENBRIDGE INC.
Entity Incorporation, State or Country Code	Z4
Entity Tax Identification Number	98-0377957
Entity Address, Address Line One	200, 425 - 1st Street S.W.
Entity Address, City or Town	Calgary
Entity Address, State or Province	AB
Entity Address, Country	CA
Entity Address, Postal Zip Code	T2P 3L8
City Area Code	403
Local Phone Number	231-3900
Title of 12(b) Security	Common Shares
Trading Symbol	ENB
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		2,125,574,412
Entity Central Index Key	0000895728
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3

CONSOLIDATED STATEMENTS OF EARN

CONSOLIDATED STATEMENTS OF EARNINGS $ in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023 CAD ($) $ / shares	Sep. 30, 2022 CAD ($) $ / shares	Sep. 30, 2023 CAD ($) $ / shares	Sep. 30, 2022 CAD ($) $ / shares
Operating revenues
Total operating revenues	$ 9,844	$ 11,573	$ 32,351	$ 39,885
Operating expenses
Operating and administrative	2,055	2,089	6,120	5,958
Depreciation and amortization	1,164	1,076	3,447	3,195
Total operating expenses	8,050	9,795	25,545	34,167
Operating income	1,794	1,778	6,806	5,718
Income from equity investments	343	536	1,338	1,537
Gain on joint venture merger transaction	0	1,076	0	1,076
Other income/(expense)
Other income/(expense)	(465)	(883)	212	(924)
Interest expense	(921)	(806)	(2,709)	(2,316)
Earnings before income taxes	751	1,701	5,647	5,091
Income tax expense	(128)	(318)	(1,157)	(1,044)
Earnings	623	1,383	4,490	4,047
Earnings attributable to noncontrolling interests	(2)	(21)	(117)	(61)
Earnings attributable to controlling interests	621	1,362	4,373	3,986
Preference share dividends	(89)	(83)	(260)	(330)
Earnings attributable to common shareholders	$ 532	$ 1,279	$ 4,113	$ 3,656
Earnings per common share attributable to common shareholders (in Canadian dollars per share) | $ / shares	$ 0.26	$ 0.63	$ 2.02	$ 1.80
Diluted earnings per common share attributable to common shareholders (in Canadian dollars per share) | $ / shares	$ 0.26	$ 0.63	$ 2.02	$ 1.80
Commodity sales
Operating revenues
Total operating revenues	$ 4,652	$ 6,415	$ 14,114	$ 22,880
Operating expenses
Commodity costs and gas distribution costs	4,648	6,300	13,833	22,772
Gas distribution sales
Operating revenues
Total operating revenues	516	695	3,587	3,698
Operating expenses
Commodity costs and gas distribution costs	183	330	2,145	2,242
Transportation and other services
Operating revenues
Total operating revenues	$ 4,676	$ 4,463	$ 14,650	$ 13,307

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Comprehensive Income [Abstract]
Earnings	$ 623	$ 1,383	$ 4,490	$ 4,047
Other comprehensive income/(loss), net of tax
Change in unrealized gain on cash flow hedges	238	171	359	817
Change in unrealized gain/(loss) on net investment hedges	(358)	(934)	42	(1,187)
Other comprehensive income/(loss) from equity investees	7	(7)	7	(7)
Excluded components of fair value hedges	2	(33)	11	(38)
Reclassification to earnings of loss on cash flow hedges	39	36	58	145
Reclassification to earnings of pension and other postretirement benefits (OPEB) amounts	(5)	(2)	(13)	(7)
Reclassification to earnings of loss on equity investees	0	16	0	16
Foreign currency translation adjustments	1,386	4,135	(131)	5,308
Other comprehensive income, net of tax	1,309	3,382	333	5,047
Comprehensive income	1,932	4,765	4,823	9,094
Comprehensive income attributable to noncontrolling interests	(45)	(116)	(143)	(187)
Comprehensive income attributable to controlling interests	1,887	4,649	4,680	8,907
Preference share dividends	(89)	(83)	(260)	(330)
Comprehensive income attributable to common shareholders	$ 1,798	$ 4,566	$ 4,420	$ 8,577

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - CAD ($) $ in Millions	Total	Total Enbridge Inc. shareholders’ equity	Preference shares	Common shares	Additional paid-in capital	Deficit	Accumulated other comprehensive income (loss)	Noncontrolling interests
Balance at the beginning of the period at Dec. 31, 2021			$ 7,747	$ 64,799	$ 365	$ (10,989)	$ (1,096)	$ 2,542
Increase (Decrease) in Stockholders' Equity
Redemption of preference shares			(929)
Shares issued, net of issue costs				0
Shares issued on exercise of stock options				50	(47)
Vested RSUs, net of withholding tax					0
Purchase of noncontrolling interests					0			0
Shares issued on vesting of restricted stock units (RSU)				0
Share purchases at stated value				(88)
Other				(4)	(33)
Stock-based compensation					27
Earnings attributable to controlling interests	$ 3,986					3,986
Preference share dividends						(330)
Common share dividends declared						(3,484)
Share purchases in excess of stated value						(63)
Other comprehensive income attributable to common shareholders, net of tax							4,921
Earnings attributable to noncontrolling interests								61
Change in unrealized gain/(loss) on cash flow hedges								(14)
Foreign currency translation adjustments								140
Other comprehensive income/(loss) attributable to noncontrolling interests, net of tax								126
Comprehensive income attributable to noncontrolling interests	(187)							187
Distributions								(189)
Contributions								10
Other								48
Balance at the end of the period at Sep. 30, 2022	$ 67,430	$ 64,832	6,818	64,757	312	(10,880)	3,825	2,598
Increase (Decrease) in Stockholders' Equity
Common stock, dividends per share, paid (in canadian dollars per share)	$ 2.58
Balance at the beginning of the period at Jun. 30, 2022			6,818	64,755	305	(10,418)	538	2,539
Increase (Decrease) in Stockholders' Equity
Redemption of preference shares			0
Shares issued, net of issue costs				0
Shares issued on exercise of stock options				2	(2)
Vested RSUs, net of withholding tax					0
Purchase of noncontrolling interests	$ 0							0
Shares issued on vesting of restricted stock units (RSU)				0
Share purchases at stated value				0
Other				0	0
Stock-based compensation					9
Earnings attributable to controlling interests	1,362					1,362
Preference share dividends						(83)
Common share dividends declared						(1,741)
Share purchases in excess of stated value						0
Other comprehensive income attributable to common shareholders, net of tax							3,287
Earnings attributable to noncontrolling interests								21
Change in unrealized gain/(loss) on cash flow hedges								(8)
Foreign currency translation adjustments								103
Other comprehensive income/(loss) attributable to noncontrolling interests, net of tax								95
Comprehensive income attributable to noncontrolling interests	(116)							116
Distributions								(62)
Contributions								2
Other								3
Balance at the end of the period at Sep. 30, 2022	$ 67,430	64,832	6,818	64,757	312	(10,880)	3,825	2,598
Increase (Decrease) in Stockholders' Equity
Common stock, dividends per share, paid (in canadian dollars per share)	$ 0.86
Balance at the beginning of the period at Dec. 31, 2022	$ 63,398		6,818	64,760	275	(15,486)	3,520	3,511
Increase (Decrease) in Stockholders' Equity
Redemption of preference shares			0
Shares issued, net of issue costs				4,485
Shares issued on exercise of stock options				3	(3)
Vested RSUs, net of withholding tax					(20)
Purchase of noncontrolling interests					(29)			2
Shares issued on vesting of restricted stock units (RSU)				12
Share purchases at stated value				(80)
Other				0	0
Stock-based compensation					53
Earnings attributable to controlling interests	4,373					4,373
Preference share dividends						(260)
Common share dividends declared						(3,591)
Share purchases in excess of stated value						(45)
Other comprehensive income attributable to common shareholders, net of tax							307
Earnings attributable to noncontrolling interests								117
Change in unrealized gain/(loss) on cash flow hedges								29
Foreign currency translation adjustments								(3)
Other comprehensive income/(loss) attributable to noncontrolling interests, net of tax								26
Comprehensive income attributable to noncontrolling interests	(143)							143
Distributions								(281)
Contributions								10
Other								(3)
Balance at the end of the period at Sep. 30, 2023	$ 68,474	65,092	6,818	69,180	276	(15,009)	3,827	3,382
Increase (Decrease) in Stockholders' Equity
Common stock, dividends per share, paid (in canadian dollars per share)	$ 2.67
Balance at the beginning of the period at Jun. 30, 2023			6,818	64,694	291	(13,746)	2,561	3,420
Increase (Decrease) in Stockholders' Equity
Redemption of preference shares			0
Shares issued, net of issue costs				4,485
Shares issued on exercise of stock options				1	(1)
Vested RSUs, net of withholding tax					(20)
Purchase of noncontrolling interests					(29)			2
Shares issued on vesting of restricted stock units (RSU)				0
Share purchases at stated value				0
Other				0	0
Stock-based compensation					35
Earnings attributable to controlling interests	$ 621					621
Preference share dividends						(89)
Common share dividends declared						(1,795)
Share purchases in excess of stated value						0
Other comprehensive income attributable to common shareholders, net of tax							1,266
Earnings attributable to noncontrolling interests								2
Change in unrealized gain/(loss) on cash flow hedges								11
Foreign currency translation adjustments								32
Other comprehensive income/(loss) attributable to noncontrolling interests, net of tax								43
Comprehensive income attributable to noncontrolling interests	(45)							45
Distributions								(86)
Contributions								2
Other								(1)
Balance at the end of the period at Sep. 30, 2023	$ 68,474	$ 65,092	$ 6,818	$ 69,180	$ 276	$ (15,009)	$ 3,827	$ 3,382
Increase (Decrease) in Stockholders' Equity
Common stock, dividends per share, paid (in canadian dollars per share)	$ 0.89

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS $ in Millions, $ in Millions	9 Months Ended
	Sep. 30, 2023 CAD ($)	Sep. 30, 2022 CAD ($)
Operating activities
Earnings	$ 4,490	$ 4,047
Adjustments to reconcile earnings to net cash provided by operating activities:
Depreciation and amortization	3,447	3,195
Deferred income tax expense	923	600
Unrealized derivative fair value (gain)/loss, net	(270)	1,691
Income from equity investments	(1,338)	(1,537)
Distributions from equity investments	1,539	1,293
Gain on joint venture merger transaction	0	(1,076)
Other	137	6
Changes in operating assets and liabilities	1,461	(602)
Net cash provided by operating activities	10,389	7,617
Investing activities
Capital expenditures	(3,284)	(3,204)
Long-term, restricted and other investments	(487)	(566)
Distributions from equity investments in excess of cumulative earnings	865	426
Additions to intangible assets	(165)	(131)
Acquisitions	(487)	(295)
Proceeds from sale of equity method investments	0	522
Affiliate loans, net	86	90
Other	(31)	0
Net cash used in investing activities	(3,503)	(3,158)
Financing activities
Net change in short-term borrowings	(412)	367
Net change in commercial paper and credit facility draws	(9,855)	386
Debenture and term note issues, net of issue costs	9,611	4,739
Debenture and term note repayments	(2,881)	(2,244)
Contributions from noncontrolling interests	10	10
Distributions to noncontrolling interests	(281)	(189)
Common shares issued, net of issue costs	4,450	3
Common shares repurchased	(125)	(151)
Preference share dividends	(260)	(254)
Common share dividends	(5,390)	(5,226)
Redemption of preference shares	0	(1,003)
Affiliate loans, net	69	0
Other	(82)	(223)
Net cash used in financing activities	(5,146)	(3,785)
Effect of translation of foreign denominated cash and cash equivalents and restricted cash	0	63
Net change in cash and cash equivalents and restricted cash	1,740	737
Cash and cash equivalents and restricted cash at beginning of period	907	320
Cash and cash equivalents and restricted cash at end of period	$ 2,647	$ 1,057

CONSOLIDATED STATEMENTS OF FINA

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - CAD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Current assets
Cash and cash equivalents	$ 2,608	$ 861
Restricted cash	39	46
Trade receivables and unbilled revenues	3,976	5,616
Other current assets	2,757	3,255
Inventory	1,566	2,255
Current assets	11,131	12,147
Property, plant and equipment, net	105,580	104,460
Long-term investments	15,271	15,936
Restricted long-term investments	635	593
Deferred amounts and other assets	9,276	9,542
Intangible assets, net	3,730	4,018
Goodwill	32,390	32,440
Deferred income taxes	397	472
Total assets	178,410	179,608
Current liabilities
Short-term borrowings	1,584	1,996
Trade payables and accrued liabilities	4,375	6,172
Other current liabilities	2,851	5,220
Interest payable	723	763
Current portion of long-term debt	7,138	6,045
Current liabilities	16,725	20,301
Long-term debt	68,793	72,939
Other long-term liabilities	9,467	9,189
Deferred income taxes	14,951	13,781
Total liabilities	109,936	116,210
Contingencies
Share capital
Preference shares	6,818	6,818
Common shares (2,126 and 2,025 outstanding at September 30, 2023 and December 31, 2022, respectively)	69,180	64,760
Additional paid-in capital	276	275
Deficit	(15,009)	(15,486)
Accumulated other comprehensive income	3,827	3,520
Total Enbridge Inc. shareholders’ equity	65,092	59,887
Noncontrolling interests	3,382	3,511
Equity	68,474	63,398
Total liabilities and equity	178,410	179,608
Related Party
Current assets
Accounts receivable from affiliates	185	114
Current liabilities
Accounts payable to affiliates	$ 54	$ 105

CONSOLIDATED STATEMENTS OF FI_2

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION (Parenthetical) - shares shares in Millions	Sep. 30, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Common shares, outstanding (in shares)	2,126	2,025

BASIS OF PRESENTATION

BASIS OF PRESENTATION	9 Months Ended
	Sep. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
BASIS OF PRESENTATION	BASIS OF PRESENTATION The accompanying unaudited interim consolidated financial statements of Enbridge Inc. ("we", "our", "us" and "Enbridge") have been prepared in accordance with generally accepted accounting principles in the United States of America (US GAAP) and Regulation S-X for interim consolidated financial information. They do not include all 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, 2022. In the opinion of management, the interim consolidated financial statements contain all 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 follow the same significant accounting policies as those included in our audited consolidated financial statements for the year ended December 31, 2022. Amounts are stated in Canadian dollars unless otherwise noted. Our operations and earnings for interim periods can be affected by seasonal fluctuations within the gas distribution utility businesses, as well 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.

REVENUES

REVENUES	9 Months Ended
	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
REVENUES	REVENUES REVENUE FROM CONTRACTS WITH CUSTOMERS Major Products and Services Three months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 2,856 1,294 148 — — — 4,298 Storage and other revenue 65 118 83 — — — 266 Gas distribution revenue — — 528 — — — 528 Electricity revenue — — — 79 — — 79 Total revenue from contracts with customers 2,921 1,412 759 79 — — 5,171 Commodity sales — — — — 4,652 — 4,652 Other revenue 1,2 61 11 (9) (42) — — 21 Intersegment revenue 102 — 1 3 6 (112) — Total revenue 3,084 1,423 751 40 4,658 (112) 9,844 Three months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 2,962 1,264 143 — — — 4,369 Storage and other revenue 58 91 63 — — — 212 Gas distribution revenue — — 699 — — — 699 Electricity revenue — — — 68 — — 68 Total revenue from contracts with customers 3,020 1,355 905 68 — — 5,348 Commodity sales — — — — 6,415 — 6,415 Other revenue 1,2 (258) 10 3 54 — 1 (190) Intersegment revenue 137 1 1 (2) 4 (141) — Total revenue 2,899 1,366 909 120 6,419 (140) 11,573 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 8,800 3,968 593 — — — 13,361 Storage and other revenue 191 326 267 — — — 784 Gas distribution revenue — — 3,611 — — — 3,611 Electricity revenue — — — 220 — — 220 Total revenue from contracts with customers 8,991 4,294 4,471 220 — — 17,976 Commodity sales — — — — 14,114 — 14,114 Other revenue 1,2 170 29 (50) 112 — — 261 Intersegment revenue 358 1 5 2 24 (390) — Total revenue 9,519 4,324 4,426 334 14,138 (390) 32,351 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 8,212 3,658 551 — — — 12,421 Storage and other revenue 173 258 209 — — — 640 Gas gathering and processing revenue — 21 — — — — 21 Gas distribution revenue — — 3,716 — — — 3,716 Electricity revenue — — — 211 — — 211 Total revenue from contracts with customers 8,385 3,937 4,476 211 — — 17,009 Commodity sales — — — — 22,880 — 22,880 Other revenue 1,2 (225) 28 (30) 222 — 1 (4) Intersegment revenue 432 2 12 (2) 14 (458) — Total revenue 8,592 3,967 4,458 431 22,894 (457) 39,885 1 Includes realized and unrealized gains and losses from our hedging program which for the three months ended September 30, 2023 were a net $97 million loss (2022 - $345 million loss) and for the nine months ended September 30, 2023 were a net $149 million loss (2022 - $483 million loss). 2 Includes revenues from lease contracts for the three months ended September 30, 2023 and 2022 of $107 million and $128 million, respectively, and for the nine months ended September 30, 2023 and 2022 of $387 million and $435 million, respectively. We disaggregate revenues 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 Receivables Contract Assets Contract Liabilities (millions of Canadian dollars) Balance as at September 30, 2023 2,161 230 2,448 Balance as at December 31, 2022 3,183 230 2,241 Contract receivables represent the amount of receivables derived from contracts with customers. Contract assets represent the amount of revenues which has been recognized in advance of payments received for performance obligations we have fulfilled (or have partially fulfilled) and prior to the point in time at which our right to payment is unconditional. Amounts included in contract assets are transferred to accounts receivable when our right to receive the consideration becomes unconditional. Contract liabilities represent payments received for performance obligations which have not been fulfilled. Contract liabilities primarily relate to make-up rights and deferred revenues. Revenue recognized during the three and nine months ended September 30, 2023 included in contract liabilities at the beginning of the period was $90 million and $179 million, respectively. Increases in contract liabilities from cash received, net of amounts recognized as revenues, during the three and nine months ended September 30, 2023 were $213 million and $380 million, respectively. Performance Obligations There were no material revenues recognized in the three and nine months ended September 30, 2023 from performance obligations satisfied in previous periods. Revenues to be Recognized from Unfulfilled Performance Obligations Total revenues from performance obligations expected to be fulfilled in future periods is $57.5 billion, of which $2.0 billion and $6.6 billion are expected to be recognized during the remaining three months ending December 31, 2023 and the year ending December 31, 2024, 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 overall 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 revenues to be recognized in the future from unfulfilled performance obligations above. Variable consideration is excluded from the amounts above due to the uncertainty of the associated consideration, which is generally 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. Additionally, the effect of escalation on certain tolls which are contractually 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 tolls are periodically reset by the regulator are excluded from the amounts above since future tolls remain unknown. Finally, revenues from contracts with customers which have an original expected duration of one year or less are excluded from the amounts above. Variable Consideration During the first six months of 2023, revenue for the Canadian Mainline was recognized in accordance with the terms of the Competitive Tolling Settlement (CTS), which expired on June 30, 2021. The tolls in place on June 30, 2021 continued on an interim basis until July 1, 2023 when new interim tolls took effect. Until a new commercial arrangement is approved, the tolls are subject to finalization and adjustment applicable to the interim period, if any. Due to the uncertainty of adjustment to tolling pursuant to a Canada Energy Regulator (CER) decision and potential customer negotiations, interim toll revenue recognized during the three and nine months ended September 30, 2023 is considered variable consideration. Recognition and Measurement of Revenues Three months ended September 30, 2023 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 38 — 38 Revenues from products and services transferred over time 1 2,921 1,412 721 79 5,133 Total revenue from contracts with customers 2,921 1,412 759 79 5,171 Three months ended September 30, 2022 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 41 — 41 Revenues from products and services transferred over time 1 3,020 1,355 864 68 5,307 Total revenue from contracts with customers 3,020 1,355 905 68 5,348 Nine months ended September 30, 2023 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 105 — 105 Revenues from products and services transferred over time 1 8,991 4,294 4,366 220 17,871 Total revenue from contracts with customers 8,991 4,294 4,471 220 17,976 Nine months ended September 30, 2022 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 77 — 77 Revenues from products and services transferred over time 1 8,385 3,937 4,399 211 16,932 Total revenue from contracts with customers 8,385 3,937 4,476 211 17,009 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.

SEGMENTED INFORMATION

SEGMENTED INFORMATION	9 Months Ended
	Sep. 30, 2023
Segment Reporting [Abstract]
SEGMENTED INFORMATION	SEGMENTED INFORMATION Three months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 3,084 1,423 751 40 4,658 (112) 9,844 Commodity and gas distribution costs — 1 (190) (13) (4,749) 120 (4,831) Operating and administrative (1,088) (578) (305) (63) (10) (11) (2,055) Income/(loss) from equity investments 231 94 — 21 — (3) 343 Other income/(expense) 20 33 15 45 (5) (573) (465) Earnings/(loss) before interest, income taxes and depreciation and amortization 2,247 973 271 30 (106) (579) 2,836 Depreciation and amortization (1,164) Interest expense (921) Income tax expense (128) Earnings 623 Capital expenditures 1 598 989 679 54 — 27 2,347 Three months ended September 30, 2022 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 2,899 1,366 909 120 6,419 (140) 11,573 Commodity and gas distribution costs 27 — (327) (5) (6,465) 140 (6,630) Operating and administrative (1,173) (545) (311) (58) (9) 7 (2,089) Income from equity investments 193 321 — 22 — — 536 Gain on joint venture merger transaction (Note 5) — 1,076 — — — — 1,076 Other income/(expense) — 33 15 26 (15) (942) (883) Earnings/(loss) before interest, income taxes and depreciation and amortization 1,946 2,251 286 105 (70) (935) 3,583 Depreciation and amortization (1,076) Interest expense (806) Income tax expense (318) Earnings 1,383 Capital expenditures 1 268 525 405 9 — 8 1,215 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 9,519 4,324 4,426 334 14,138 (390) 32,351 Commodity and gas distribution costs — 1 (2,173) (19) (14,179) 392 (15,978) Operating and administrative (3,294) (1,715) (939) (178) (40) 46 (6,120) Income/(loss) from equity investments 733 531 1 83 — (10) 1,338 Other income/(expense) 103 79 39 75 (2) (82) 212 Earnings/(loss) before interest, income taxes and depreciation and amortization 7,061 3,220 1,354 295 (83) (44) 11,803 Depreciation and amortization (3,447) Interest expense (2,709) Income tax expense (1,157) Earnings 4,490 Capital expenditures 1 835 1,332 1,025 77 — 54 3,323 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 8,592 3,967 4,458 431 22,894 (457) 39,885 Commodity and gas distribution costs — — (2,258) (13) (23,197) 454 (25,014) Operating and administrative (3,096) (1,620) (891) (159) (34) (158) (5,958) Income/(loss) from equity investments 561 877 1 100 — (2) 1,537 Gain on joint venture merger transaction (Note 5) — 1,076 — — — — 1,076 Other income/(expense) 36 84 58 30 (11) (1,121) (924) Earnings/(loss) before interest, income taxes and depreciation and amortization 6,093 4,384 1,368 389 (348) (1,284) 10,602 Depreciation and amortization (3,195) Interest expense (2,316) Income tax expense (1,044) Earnings 4,047 Capital expenditures 1 1,086 1,087 1,005 26 — 32 3,236 1 Includes allowance for equity funds used during construction.

EARNINGS PER COMMON SHARE AND D

EARNINGS PER COMMON SHARE AND DIVIDENDS PER SHARE	9 Months Ended
	Sep. 30, 2023
Earnings Per Share [Abstract]
EARNINGS PER COMMON SHARE AND DIVIDENDS PER SHARE	EARNINGS PER COMMON SHARE AND DIVIDENDS PER SHARE BASIC Earnings per common share is calculated by dividing earnings attributable to common shareholders by the weighted average number of common shares outstanding. DILUTED The treasury stock method is used to determine the dilutive impact of stock options and RSUs. This method assumes any proceeds from the exercise of stock options and vesting of RSUs 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 follows: Three months ended Nine months ended 2023 2022 2023 2022 (number of shares in millions) Weighted average shares outstanding 2,048 2,025 2,033 2,026 Effect of dilutive options and RSUs 1 3 2 3 Diluted weighted average shares outstanding 2,049 2,028 2,035 2,029 For the three months ended September 30, 2023 and 2022, 21.6 million and 11.4 million, respectively, of anti-dilutive stock options with a weighted average exercise price of $53.69 and $56.49, respectively, were excluded from the diluted earnings per common share calculation. For the nine months ended September 30, 2023 and 2022, 18.2 million and 9.2 million, respectively, of anti-dilutive stock options with a weighted average exercise price of $54.81 and $56.63, respectively, were excluded from the diluted earnings per common share calculation. DIVIDENDS PER SHARE On October 31, 2023, our Board of Directors declared the following quarterly dividends. All dividends are payable on December 1, 2023 to shareholders of record on November 15, 2023. Dividend per share Common Shares 1 $0.88750 Preference Shares, Series A $0.34375 Preference Shares, Series B $0.32513 Preference Shares, Series D 2 $0.33825 Preference Shares, Series F 3 $0.34613 Preference Shares, Series G 4 $0.47245 Preference Shares, Series H 5 $0.38200 Preference Shares, Series I 6 $0.44814 Preference Shares, Series L US$0.36612 Preference Shares, Series N $0.31788 Preference Shares, Series P $0.27369 Preference Shares, Series R $0.25456 Preference Shares, Series 1 7 US$0.41898 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 8 $0.38825 1 The quarterly dividend per common share was increased 3.2% to $0.8875 from $0.86, effective March 1, 2023. 2 The quarterly dividend per share paid on Preference Shares, Series D was increased to $0.33825 from $0.27875 on March 1, 2023 due to reset of the annual dividend on March 1, 2023. 3 The quarterly dividend per share paid on Preference Shares, Series F was increased to $0.34613 from $0.29306 on June 1, 2023 due to reset of the annual dividend on June 1, 2023. 4 On June 1, 2023, 1,827,695 of the outstanding Preference Shares, Series F were converted into Preference Shares, Series G. The quarterly dividend per share paid on Preference Shares, Series G was increased to $0.47245 from $0.43858 on September 1, 2023 due to reset on a quarterly basis following the date of issuance. 5 The quarterly dividend per share paid on Preference Shares, Series H was increased to $0.38200 from $0.27350 on September 1, 2023 due to reset of the annual dividend on September 1, 2023. 6 On September 1, 2023, 2,350,602 of the outstanding Preference Shares, Series H were converted into Preference Shares, Series I. The first quarterly dividend on Preference Shares, Series I will be paid on December 1, 2023. 7 The quarterly dividend per share paid on Preference Shares, Series 1 was increased to US$0.41898 from US$0.37182 on June 1, 2023 due to reset of the annual dividend on June 1, 2023. 8 The quarterly dividend per share paid on Preference Shares, Series 19 was increased to $0.38825 from $0.30625 on March 1, 2023 due to reset of the annual dividend on March 1, 2023.

ACQUISITION AND DISPOSITIONS

ACQUISITION AND DISPOSITIONS	9 Months Ended
	Sep. 30, 2023
Business Combination and Asset Acquisition [Abstract]
ACQUISITION AND DISPOSITIONS	ACQUISITIONS AND DISPOSITIONS ACQUISITIONS OF US GAS UTILITIES On September 5, 2023, we announced that Enbridge had entered into three separate definitive agreements with Dominion Energy, Inc. to acquire The East Ohio Gas Company, Questar Gas Company and its related Wexpro companies, and Public Service Company of North Carolina for an aggregate purchase price of $19.1 billion (US$14.0 billion), comprised of $12.8 billion (US$9.4 billion) of cash consideration and $6.3 billion (US$4.6 billion) of assumed debt, subject to customary closing adjustments (together, the Acquisitions). The Acquisitions are expected to close in 2024, subject to the satisfaction of customary closing conditions including the receipt of certain regulatory approvals, which are not cross conditional. On September 8, 2023, we closed a public offering of 102,913,500 common shares at a price of $44.70 per share for gross proceeds of $4.6 billion which is intended to finance a portion of the aggregate cash consideration payable for the Acquisitions. In September 2023, we closed two offerings for aggregate principal amounts of US$2.0 billion and $1.0 billion. The proceeds from the offerings are intended to finance a portion of the aggregate cash consideration payable for the Acquisitions. Refer to Note 6 - Debt for further details on the debt issuances and credit facility obtained to support the Acquisitions. TRES PALACIOS HOLDINGS LLC On April 3, 2023, we acquired Tres Palacios Holdings LLC (Tres Palacios) for $451 million (US$335 million) of cash. Tres Palacios is a natural gas storage facility located in the United States (US) Gulf Coast and its infrastructure serves Texas gas-fired power generation and liquefied natural gas exports, as well as Mexico pipeline exports. We allocated assets with a fair value of $790 million (US$588 million) to Property, plant and equipment, net, of which $254 million (US$189 million) relates to storage cavern right-of-use assets, and recorded the related lease liabilities of $7 million (US$5 million) and $248 million (US$184 million) to Current portion of long-term debt and Long-term debt, respectively, in the Consolidated Statements of Financial Position. The acquired assets are included in our Gas Transmission and Midstream segment. DCP MIDSTREAM, LLC On August 17, 2022, we completed a joint venture merger transaction with Phillips 66 resulting in a single joint venture, DCP Midstream, LLC, holding both our and Phillips 66's indirect ownership interests in Gray Oak Pipeline, LLC (Gray Oak) and DCP Midstream, LP (DCP). Our ownership in DCP Midstream, LLC consists of Class A and Class B Interests which track to our investments in DCP, included in the Gas Transmission and Midstream segment, and Gray Oak, included in the Liquids Pipelines segment, respectively. Through our investment in DCP Midstream, LLC, we increased our effective economic interest in Gray Oak to 58.5% from 22.8% and reduced our effective economic interest in DCP to 13.2% from 28.3%. As a result of the transaction, Enbridge assumed operatorship of Gray Oak in the second quarter of 2023. We determined the fair value of our decrease in economic interest in DCP based on the unadjusted quoted market price of DCP’s publicly traded common units on the transaction closing date. The fair value of our increased economic interest in Gray Oak was determined using the fair value prescribed to the change in our economic interest in DCP. As a result of the merger transaction and the realignment of our economic interests in DCP and Gray Oak, we also received cash consideration of approximately $522 million (US$404 million) and recorded an accounting gain of $1.1 billion (US$832 million) to Gain on joint venture merger transaction in the Consolidated Statements of Earnings. Both DCP and Gray Oak continue to be accounted for as equity method investments. TRI GLOBAL ENERGY, LLC On September 27, 2022, through a wholly-owned US subsidiary, we acquired all of the outstanding common units in Tri Global Energy, LLC (TGE) for cash consideration of $295 million (US$215 million) plus potential contingent payments of up to $72 million (US$53 million) dependent on the achievement of performance milestones by TGE (the TGE Acquisition). TGE is an onshore renewable project developer in the US with a development portfolio of wind and solar projects. The TGE Acquisition enhances Enbridge's renewable power platform and accelerates our North American growth strategy. We accounted for the TGE Acquisition using the acquisition method as prescribed by ASC 805 Business Combinations . In accordance with valuation methodologies described in ASC 820 Fair Value Measurements , the acquired assets and assumed liabilities are recorded at their estimated fair values as at the date of acquisition. The following table summarizes the estimated fair values that were assigned to the net assets of TGE: September 27, 2022 (millions of Canadian dollars) Fair value of net assets acquired: Current assets 5 Property, plant and equipment 3 Long-term investments 8 Intangible assets (a) 117 Long-term assets 3 Current liabilities 61 Long-term debt 18 Long-term liabilities (b) 105 Goodwill (c) 392 Purchase price: Cash 295 Contingent consideration (d) 49 344 a) Intangible assets consist of compensation expected to be earned by TGE on existing development contracts once certain project development milestones are met. Fair value was determined using a discounted cash flow method which is an income-based approach to valuation that estimates the present value of future projected benefits from the contracts. The intangible assets will be amortized on a straight-line basis over an expected useful life of three and a half years. b) Long-term liabilities consist primarily of obligations payable to third parties which are contingent on milestones being met for certain projects. Fair value represents the present value of the future cash flow payments at the date of the TGE Acquisition. c) Goodwill is primarily attributable to expected future returns from new opportunities to develop wind and solar projects, as well as enhanced scale and operational diversity of our renewable projects portfolio. The goodwill balance recognized has been assigned to our Renewable Power Generation segment and is tax deductible over 15 years. d) We agreed to pay additional contingent consideration of up to US$53 million to TGE's former common unit holders if performance milestones are met on certain projects. The US$36 million of contingent consideration recognized in the purchase price represents the fair value of contingent consideration at the date of acquisition. The fair value was determined using an income-based approach. Upon completion of the TGE Acquisition, we began consolidating TGE. For the period beginning September 27, 2022 through to September 30, 2022, operating revenues and earnings attributable to common shareholders generated by TGE were immaterial. The impact to our supplemental pro forma consolidated operating revenues and earnings attributable to common shareholders for the three and nine months ended September 30, 2022, as if the TGE Acquisition had been completed on January 1, 2021, was also immaterial. ATHABASCA REGIONAL OIL SANDS SYSTEM On September 28, 2022, we entered into an agreement to sell an 11.6% non-operating interest in seven pipelines in the Athabasca region of northern Alberta from our Regional Oil Sands System to Athabasca Indigenous Investments Limited Partnership, an entity representing 23 First Nation and Métis communities. On October 5, 2022, we closed the sale for total consideration of approximately $1.1 billion, less customary closing adjustments. Subsequent to the sale, we maintained an 88.4% controlling interest in these assets, which are a component of our Liquids Pipelines segment, and continue to manage, operate and provide administrative services to them.

DEBT

DEBT	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
DEBT	DEBT CREDIT FACILITIES The following table provides details of our committed credit facilities as at September 30, 2023: Maturity 1 Total Draws 2 Available (millions of Canadian dollars) Enbridge Inc. 2024-2028 8,853 1,272 7,581 Enbridge (U.S.) Inc. 2025-2028 8,585 1,064 7,521 Enbridge Pipelines Inc. 2025 2,000 265 1,735 Enbridge Gas Inc. 2025 2,500 1,585 915 Total committed credit facilities 21,938 4,186 17,752 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. In March 2023, Enbridge Gas Inc. (Enbridge Gas) increased its 364-day extendible credit facility from $2.0 billion to $2.5 billion and in July 2023, the facility's maturity date was extended to July 2025, which includes a one-year term out provision from July 2024. In July 2023, Enbridge Pipelines Inc. extended the maturity date of its 364-day extendible credit facility to July 2025, which includes a one-year term out provision from July 2024. In July 2023, we renewed approximately $6.8 billion of our 364-day extendible credit facilities, extending the maturity dates to July 2025, which includes a one-year term out provision from July 2024. We also renewed approximately $7.6 billion of our five-year credit facilities, extending the maturity dates to July 2028. Further, we extended our three-year credit facilities, extending the maturity dates to July 2026. In September 2023, we obtained commitments for a US$9.4 billion senior unsecured bridge term loan credit facility to support the Acquisitions. The commitment for this facility was subsequently reduced to US$3.4 billion as at September 30, 2023 as a result of the $4.6 billion equity offering and the September 2023 subordinated long-term debt issuances. In addition to the committed credit facilities noted above, we maintain $1.3 billion of uncommitted demand letter of credit facilities, of which $712 million was unutilized as at September 30, 2023. As at December 31, 2022, we had $1.3 billion of uncommitted demand letter of credit facilities, of which $689 million was unutilized. Our credit facilities, excluding the bridge term loan facility, 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 2024 to 2028. As at September 30, 2023 and December 31, 2022, commercial paper and credit facility draws, net of short-term borrowings and non-revolving credit facilities that mature within one year, of $2.1 billion and $10.5 billion, respectively, were supported by the availability of long-term committed credit facilities and, therefore, have been classified as long-term debt. LONG-TERM DEBT ISSUANCES During the nine months ended September 30, 2023, we completed the following long-term debt issuances totaling US$5.0 billion and $2.9 billion: Company Issue Date Principal Amount (millions of Canadian dollars, unless otherwise stated) Enbridge Inc. March 2023 5.70% sustainability-linked senior notes due March 2033 1 US$2,300 March 2023 5.97% senior notes due March 2026 2 US$700 May 2023 4.90% medium-term notes due May 2028 $600 May 2023 5.36% sustainability-linked medium-term notes due May 2033 3 $400 May 2023 5.76% medium-term notes due May 2053 $500 September 2023 8.50% fixed-to-fixed subordinated notes due January 2084 4 US$1,250 September 2023 8.25 % fixed-to-fixed subordinated notes due January 2084 5 US$750 September 2023 8.75 % fixed-to-fixed subordinated notes due January 2084 6 $700 September 2023 8.50 % fixed-to-fixed subordinated notes due January 2084 7 $300 Enbridge Pipelines Inc. August 2023 5.82% medium-term notes due August 2053 $350 1 The sustainability-linked senior notes are subject to a sustainability performance target of 35% reduction in emissions intensity from 2018 levels at an observation date of December 31, 2030. If the target is not met, on September 8, 2031, the interest rate will be set to equal 5.70% plus 50 basis points. 2 We have the option to call the notes at par after one year from issuance. Refer to Note 8 - Risk Management and Financial Instruments. 3 The sustainability-linked senior notes are subject to a sustainability performance target of 35% reduction in emissions intensity from 2018 levels at an observation date of December 31, 2030. If the target is not met, on November 26, 2031, the interest rate will be set to equal 5.36% plus 50 basis points. 4 For the initial 10 years, the notes carry a fixed interest rate. At year 10, the interest rate will be reset to equal to the Five-Year US Treasury rate plus a margin of 4.43%. Subsequent to year 10, every five years, the Five-year US treasury rate is reset. At year 30, the interest rate will be reset to equal to the Five-Year US Treasury rate plus a margin of 5.18%. 5 For the initial five 6 For the initial 10 years, the notes carry a fixed interest rate. At year 10, the interest rate will be reset to equal to the Five-Year Government of Canada bond yield plus a margin of 4.96%. Subsequent to year 10, every five years, the Government of Canada bond yield rate is reset. At year 30, the interest rate will be reset to equal to the Five-Year Government of Canada bond yield plus a margin of 5.71%. 7 For the initial five In October 2023, Enbridge Gas closed a three-tranche offering consisting of five LONG-TERM DEBT REPAYMENTS During the nine months ended September 30, 2023, we completed the following long-term debt repayments totaling US$1.2 billion and $1.3 billion: Company Repayment Date Principal Amount (millions of Canadian dollars, unless otherwise stated) Enbridge Inc. January 2023 3.94% medium-term notes $275 February 2023 Floating rate notes 1 US$500 April 2023 6.38% fixed-to-floating rate subordinated notes 2 US$600 June 2023 3.94% medium-term notes $450 Enbridge Gas Inc. July 2023 6.05% medium-term notes $100 July 2023 3.79% medium-term notes $250 Enbridge Pipelines (Southern Lights) L.L.C. June 2023 3.98% senior notes US$38 Enbridge Pipelines Inc. August 2023 3.79% medium-term notes $250 Enbridge Southern Lights LP June 2023 4.01% senior notes $9 Tri Global Energy, LLC January 2023 10.00% senior notes US$4 January 2023 14.00% senior notes US$9 1 The notes carried an interest rate set to equal the Secured Overnight Financing Rate plus a margin of 40 basis points. 2 The five-year callable notes, with an original maturity date of April 2078, were all redeemed at par. SUBORDINATED TERM NOTES As at September 30, 2023 and December 31, 2022, our fixed-to-floating rate and fixed-to-fixed rate subordinated term notes had a principal value of $13.2 billion and $10.3 billion, respectively. FAIR VALUE ADJUSTMENT As at September 30, 2023 and December 31, 2022, the net fair value adjustments to total debt assumed in a historical acquisition were $551 million and $608 million, respectively. Amortization of the fair value adjustment is recorded as a reduction to Interest expense in the Consolidated Statements of Earnings: Three months ended September 30, Nine months ended September 30, 2023 2022 2023 2022 (millions of Canadian dollars) Amortization of fair value adjustment 12 11 34 33 DEBT COVENANTS Our 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 September 30, 2023, we were in compliance with all covenant provisions.

COMPONENTS OF ACCUMULATED OTHER

COMPONENTS OF ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)	9 Months Ended
	Sep. 30, 2023
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
COMPONENTS OF ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)	COMPONENTS OF ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) Changes in Accumulated other comprehensive income/(loss) (AOCI) attributable to our common shareholders for the nine months ended September 30, 2023 and 2022 are as follows: Cash Excluded Net Cumulative Equity Pension Total (millions of Canadian dollars) Balance as at January 1, 2023 121 (35) (1,137) 4,348 5 218 3,520 Other comprehensive income/(loss) retained in AOCI 447 11 42 (128) 8 — 380 Other comprehensive loss/(income) reclassified to earnings Interest rate contracts 1 63 — — — — — 63 Other contracts 2 1 — — — — — 1 Amortization of pension and OPEB actuarial gain 3 — — — — — (16) (16) 511 11 42 (128) 8 (16) 428 Tax impact Income tax on amounts retained in AOCI (117) — — — (1) — (118) Income tax on amounts reclassified to earnings (6) — — — — 3 (3) (123) — — — (1) 3 (121) Balance as at September 30, 2023 509 (24) (1,095) 4,220 12 205 3,827 Cash Excluded Net Cumulative Equity Pension Total (millions of Canadian dollars) Balance as at January 1, 2022 (897) — (166) 56 (5) (84) (1,096) Other comprehensive income/(loss) retained in AOCI 1,073 (38) (1,187) 5,168 (6) — 5,010 Other comprehensive loss/(income) reclassified to earnings Interest rate contracts 1 187 — — — — — 187 Foreign exchange contracts 4 (4) — — — — — (4) Other contracts 2 3 — — — — — 3 Amortization of pension and OPEB actuarial gain 3 — — — — — (9) (9) Other — — — — 16 — 16 1,259 (38) (1,187) 5,168 10 (9) 5,203 Tax impact Income tax on amounts retained in AOCI (242) — — — (1) — (243) Income tax on amounts reclassified to earnings (41) — — — — 2 (39) (283) — — — (1) 2 (282) Balance as at September 30, 2022 79 (38) (1,353) 5,224 4 (91) 3,825 1 Reported within Interest expense in the Consolidated Statements of Earnings. 2 Reported within Operating and administrative expense in the Consolidated Statements of Earnings. 3 These components are included in the computation of net periodic benefit credit and are reported within Other income/(expense) in the Consolidated Statements of Earnings. 4 Reported within Transportation and other services revenues and Other income/(expense) in the Consolidated Statements of Earnings.

RISK MANAGEMENT AND FINANCIAL I

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS	RISK MANAGEMENT AND FINANCIAL INSTRUMENTS MARKET RISK Our 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 (collectively, market risks). Formal risk management policies, processes and systems have been designed to mitigate these risks. The following 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 Risk We generate certain revenues, incur expenses and hold a number of investments and subsidiaries that are denominated in currencies other than Canadian dollars. 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 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 US dollar-denominated investments and subsidiaries using foreign currency derivatives and US dollar-denominated debt. The foreign exchange risks inherent within the CTS framework are not present in the negotiated settlement. Accordingly, our foreign exchange hedging program related to the Canadian Mainline will no longer be required, and the related derivatives were terminated in the first quarter of 2023 for a realized loss of $638 million. Interest Rate Risk Our 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 hedging program to partially mitigate the impact of short-term interest rate volatility on interest expense via the execution of floating-to-fixed interest rate swaps and costless collars. These swaps have an average fixed rate of 4.2% . On March 8, 2023, we issued US$700 million three-year fixed rate notes, which include the right for us to call at par after the first year. A corresponding fix-to-floating cancellable swap was also executed which gives the swap counterparty a similar right to cancel the swap after the first year. This swap has a fixed rate of 6.0%. 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 partially mitigate our exposure to long-term interest rate variability on forecas ted term debt issuances via the execution of floating-to-fixed interest rate swaps with an average swap rate of 2.7%. Commodity Price Risk Our earnings and cash flows are exposed to changes in commodity prices as a result of our ownership interests in certain assets and investments, as well as through the activities of our energy services subsidiaries. These commodities include natural gas, crude oil, power and natural gas liquids (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. Equity Price Risk Equity 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 the revaluation of outstanding units every period. We use equity derivatives to manage the earnings volatility derived from one form of stock-based compensation, RSUs. We use a combination of qualifying and non-qualifying derivative instruments to manage equity price risk. TOTAL DERIVATIVE INSTRUMENTS We generally have a policy of entering into individual International Swaps and Derivatives Association, Inc. (ISDA) 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 following table summarizes the Consolidated Statements of Financial Position location and carrying value of our derivative instruments, as well as the maximum potential settlement amounts, in the event of the specific circumstances described above. All amounts are presented gross in the Consolidated Statements of Financial Position. September 30, 2023 Derivative Derivative Non- Total Gross Amounts Total Net (millions of Canadian dollars) Other current assets Foreign exchange contracts — 71 32 103 (25) 78 Interest rate contracts 318 — 66 384 (3) 381 Commodity contracts — — 206 206 (153) 53 318 71 304 693 (181) 512 Deferred amounts and other assets Foreign exchange contracts — 31 109 140 (90) 50 Interest rate contracts 130 — 19 149 — 149 Commodity contracts — — 57 57 (36) 21 130 31 185 346 (126) 220 Other current liabilities Foreign exchange contracts — (49) (163) (212) 25 (187) Interest rate contracts — — (3) (3) 3 — Commodity contracts (19) — (343) (362) 153 (209) Other contracts — — (2) (2) — (2) (19) (49) (511) (579) 181 (398) Other long-term liabilities Foreign exchange contracts — (36) (1,004) (1,040) 90 (950) Interest rate contracts (2) — — (2) — (2) Commodity contracts (10) — (166) (176) 36 (140) Other contracts (1) — (1) (2) — (2) (13) (36) (1,171) (1,220) 126 (1,094) Total net derivative asset/(liability) Foreign exchange contracts — 17 (1,026) (1,009) — (1,009) Interest rate contracts 446 — 82 528 — 528 Commodity contracts (29) — (246) (275) — (275) Other contracts (1) — (3) (4) — (4) 416 17 (1,193) (760) — (760) December 31, 2022 Derivative Derivative Non- Total Gross Amounts Total Net (millions of Canadian dollars) Other current assets Foreign exchange contracts — — 46 46 (41) 5 Interest rate contracts 649 — 11 660 — 660 Commodity contracts — — 302 302 (182) 120 Other contracts — — 7 7 — 7 649 — 366 1,015 (223) 792 Deferred amounts and other assets Foreign exchange contracts — 156 153 309 (138) 171 Interest rate contracts 254 — — 254 — 254 Commodity contracts — — 61 61 (25) 36 Other contracts 1 — 2 3 — 3 255 156 216 627 (163) 464 Other current liabilities Foreign exchange contracts — (42) (524) (566) 41 (525) Commodity contracts (48) — (284) (332) 182 (150) (48) (42) (808) (898) 223 (675) Other long-term liabilities Foreign exchange contracts — — (1,116) (1,116) 138 (978) Interest rate contracts (3) — (1) (4) — (4) Commodity contracts (37) — (133) (170) 25 (145) (40) — (1,250) (1,290) 163 (1,127) Total net derivative asset/(liability) Foreign exchange contracts — 114 (1,441) (1,327) — (1,327) Interest rate contracts 900 — 10 910 — 910 Commodity contracts (85) — (54) (139) — (139) Other contracts 1 — 9 10 — 10 816 114 (1,476) (546) — (546) The following table summarizes the maturity and notional principal or quantity outstanding related to our derivative instruments: September 30, 2023 2023 2024 2025 2026 2027 Thereafter Total Foreign exchange contracts - US dollar forwards - purchase (millions of US dollars) 114 1,000 500 — — — 1,614 Foreign exchange contracts - US dollar forwards - sell (millions of US dollars) 1,593 5,440 4,955 4,325 3,647 2,886 22,846 Foreign exchange contracts - British pound (GBP) forwards - sell (millions of GBP) 7 30 30 28 32 — 127 Foreign exchange contracts - Euro forwards - sell (millions of Euro) 27 91 86 85 81 262 632 Foreign exchange contracts - Japanese yen forwards - purchase (millions of yen) — — 84,800 — — — 84,800 Interest rate contracts - short-term debt pay fixed rate (millions of Canadian dollars) 2,656 5,645 1,364 1,097 75 39 10,876 Interest rate contracts - short-term debt receive fixed rate (millions of Canadian dollars) 229 946 946 179 — — 2,300 Interest rate contracts - long-term debt pay fixed rate (millions of Canadian dollars) 1,726 400 588 — — — 2,714 Interest rate contracts - costless collar (millions of Canadian dollars) — — 394 11 — — 405 Equity contracts (millions of Canadian dollars) — 33 12 — — — 45 Commodity contracts - natural gas (billions of cubic feet) 6 45 27 9 7 — 94 Commodity contracts - crude oil (millions of barrels) 5 (3) — — — — 2 Commodity contracts - power (megawatt per hour) (MW/H) 61 3 (42) (49) (53) (50) (33) 1 1 Total is an average net purchase/(sale) of power. Fair Value Derivatives For foreign exchange derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative is included in Other income/(expense) 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 Other income/(expense) in the Consolidated Statements of Earnings. Any excluded components are included in the Consolidated Statements of Comprehensive Income. Three months ended Nine months ended 2023 2022 2023 2022 (millions of Canadian dollars) Unrealized gain/(loss) on derivative 35 122 (107) 221 Unrealized gain/(loss) on hedged item (35) (122) 106 (211) Realized loss on derivative (11) (5) (34) (101) Realized gain on hedged item — — — 85 The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income The following table presents the effect of cash flow hedges and fair value hedges on our consolidated earnings and consolidated comprehensive income, before the effect of income taxes: Three months ended Nine months ended 2023 2022 2023 2022 (millions of Canadian dollars) Amount of unrealized gain/(loss) recognized in OCI Cash flow hedges Foreign exchange contracts — 1 — 3 Interest rate contracts 313 230 423 1,087 Commodity contracts 20 (16) 56 (27) Other contracts (1) (4) (3) (4) Fair value hedges Foreign exchange contracts 2 (33) 11 (38) 334 178 487 1,021 Amount of loss reclassified from AOCI to earnings Foreign exchange contracts 1 — — — 13 Interest rate contracts 2 40 45 63 187 Commodity contracts 3 1 — — — Other contracts 4 — 1 1 3 41 46 64 203 1 Reported within Transportation and other services revenues and Other income/(expense) in the Consolidated Statements of Earnings. 2 Reported within Interest expense in the Consolidated Statements of Earnings. 3 Reported within Transportation and other services in the Consolidated Statements of Earnings. 4 Reported within Operating and administrative expense in the Consolidated Statements of Earnings. We estimate that a gain of $20 million from AOCI related to cash flow hedges will 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 all forecasted transactions, the maximum term over which we are hedging exposures to the variability of cash flows is 27 months as at September 30, 2023. Non-Qualifying Derivatives The following table presents the unrealized gains and losses associated with changes in the fair value of our non-qualifying derivatives: Three months ended Nine months ended 2023 2022 2023 2022 (millions of Canadian dollars) Foreign exchange contracts 1 (650) (1,379) 415 (1,752) Interest rate contracts 2 17 17 72 1 Commodity contracts 3 (229) 89 (206) 59 Other contracts 4 (3) (3) (11) 1 Total unrealized derivative fair value gain/(loss), net (865) (1,276) 270 (1,691) 1 For the respective nine months ended periods, reported within Transportation and other services revenues (2023 - $645 million gain; 2022 - $375 million loss) and Other income/(expense) (2023 - $230 million loss; 2022 - $1,377 million loss) in the Consolidated Statements of Earnings. 2 Reported as an increase within Interest expense in the Consolidated Statements of Earnings. 3 For the respective nine months ended periods, reported within Transportation and other services revenues (2023 - $85 million loss; 2022 - $12 million gain), Commodity sales (2023 - $75 million gain; 2022 - $151 million gain), Commodity costs (2023 - $136 million loss; 2022 - $116 million loss) and Operating and administrative expense (2023 - $60 million loss; 2022 - $12 million 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 will 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 rolling time period to determine whether sufficient funds will 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. Our shelf prospectuses with securities regulators enable 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 all anticipated requirements for approximately one year without accessing the capital markets. We were in compliance with all the terms and conditions of our committed credit facility agreements and term debt indentures as at September 30, 2023. As a result, all credit facilities are available to us and the banks are obligated to fund 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 will 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 the 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. We have credit concentrations and credit exposure, with respect to derivative instruments, in the following counterparty segments: September 30, December 31, (millions of Canadian dollars) Canadian financial institutions 495 644 US financial institutions 226 277 European financial institutions 123 334 Asian financial institutions 120 224 Other 1 66 105 1,030 1,584 1 Other is comprised of commodity clearing house and physical natural gas and crude oil counterparties. As at September 30, 2023, we did not provide any letters of credit in lieu of providing cash collateral to our counterparties pursuant to the terms of the relevant ISDA agreements. We held no cash collateral on derivative asset exposures as at September 30, 2023 and December 31, 2022. Gross derivative balances have been presented without the effects of collateral 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, the assessment of credit ratings and netting arrangements. Within Enbridge Gas, 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. Generally, we utilize a loss allowance 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 MEASUREMENTS Our financial assets and liabilities measured at fair value on a recurring basis include derivatives 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 generally 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 INSTRUMENTS We 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 1 Level 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, US and Canadian treasury bills, investments in exchange-traded funds held by our captive insurance subsidiaries, as well as restricted long-term investments in exchange-traded funds that are held in trust in accordance with the CER's regulatory requirements under the Land Matters Consultation Initiative (LMCI). Level 2 Level 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 well as commodity swaps and options for which observable inputs can be obtained. We have also categorized the fair value of our long-term debt, investments in debt securities held by our captive insurance subsidiaries, 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 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 3 Level 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. Generally, 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 the 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 well 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. Finally, we consider our own credit default swap spread, as well as the credit default swap spreads associated with our counterparties, in our estimation of fair value. We have categorized our derivative assets and liabilities measured at fair value as follows: September 30, 2023 Level 1 Level 2 Level 3 Total Gross (millions of Canadian dollars) Financial assets Current derivative assets Foreign exchange contracts — 103 — 103 Interest rate contracts — 384 — 384 Commodity contracts 58 36 112 206 58 523 112 693 Long-term derivative assets Foreign exchange contracts — 140 — 140 Interest rate contracts — 149 — 149 Commodity contracts — 16 41 57 — 305 41 346 Financial liabilities Current derivative liabilities Foreign exchange contracts — (212) — (212) Interest rate contracts — (3) — (3) Commodity contracts (93) (50) (219) (362) Other contracts — (2) — (2) (93) (267) (219) (579) Long-term derivative liabilities Foreign exchange contracts — (1,040) — (1,040) Interest rate contracts — (2) — (2) Commodity contracts — (20) (156) (176) Other contracts — (2) — (2) — (1,064) (156) (1,220) Total net financial asset/(liability) Foreign exchange contracts — (1,009) — (1,009) Interest rate contracts — 528 — 528 Commodity contracts (35) (18) (222) (275) Other contracts — (4) — (4) (35) (503) (222) (760) December 31, 2022 Level 1 Level 2 Level 3 Total Gross (millions of Canadian dollars) Financial assets Current derivative assets Foreign exchange contracts — 46 — 46 Interest rate contracts — 660 — 660 Commodity contracts 65 90 147 302 Other contracts — 7 — 7 65 803 147 1,015 Long-term derivative assets Foreign exchange contracts — 309 — 309 Interest rate contracts — 254 — 254 Commodity contracts — 17 44 61 Other contracts — 3 — 3 — 583 44 627 Financial liabilities Current derivative liabilities Foreign exchange contracts — (566) — (566) Commodity contracts (60) (77) (195) (332) (60) (643) (195) (898) Long-term derivative liabilities Foreign exchange contracts — (1,116) — (1,116) Interest rate contracts — (4) — (4) Commodity contracts — (38) (132) (170) — (1,158) (132) (1,290) Total net financial asset/(liability) Foreign exchange contracts — (1,327) — (1,327) Interest rate contracts — 910 — 910 Commodity contracts 5 (8) (136) (139) Other contracts — 10 — 10 5 (415) (136) (546) The significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments were as follows: September 30, 2023 Fair Unobservable Minimum Maximum Weighted Unit of (fair value in millions of Canadian dollars) Commodity contracts - financial 1 Natural gas (20) Forward gas price 1.69 10.93 4.67 $/mmbtu 2 Crude (32) Forward crude price 83.38 120.51 98.08 $/barrel Power (77) Forward power price 30.75 160.92 65.98 $/MW/H Commodity contracts - physical 1 Natural gas (13) Forward gas price 1.58 23.92 5.04 $/mmbtu 2 Crude (19) Forward crude price 84.35 128.65 107.59 $/barrel Power (61) Forward power price 24.47 164.58 61.70 $/MW/H (222) 1 Financial and physical forward commodity contracts are valued using a market approach valuation technique. 2 One million British thermal units (mmbtu). 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 follows: Nine months ended 2023 2022 (millions of Canadian dollars) Level 3 net derivative liability at beginning of period (136) (108) Total gain/(loss) Included in earnings 1 (205) 41 Included in OCI — (28) Settlements 119 (2) Level 3 net derivative liability at end of period (222) (97) 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 September 30, 2023 or December 31, 2022. NET INVESTMENT HEDGES We currently have designated a portion of our US dollar-denominated debt as a hedge of our net investment in US dollar-denominated investments and subsidiaries. During the nine months ended September 30, 2023 and 2022, we recognized unrealized foreign exchange gains of $86 million and losses of $1,191 million, respectively, on the translation of US dollar-denominated debt, in OCI. No unrealized gains or losses on the change in fair value of our outstanding foreign exchange forward contracts were recognized in OCI during the nine months ended September 30, 2023 and 2022. No realized gains or losses associated with the settlement of foreign exchange forward contracts were recognized in OCI during the nine months ended September 30, 2023 and 2022. During the nine months ended September 30, 2023 and 2022, we recognized a realized loss of $44 million and nil, respectively, associated with the settlement of US dollar-denominated debt that had matured during the period, in OCI. FAIR VALUE OF OTHER FINANCIAL INSTRUMENTS Certain 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 $209 million and $102 million as at September 30, 2023 and December 31, 2022, respectively. As at September 30, 2023, we had investments with a fair value of $635 million included in Restricted long-term investments in the Consolidated Statements of Financial Position (December 31, 2022 - $593 million). These securities are classified as available-for-sale and represent restricted funds which are collected from customers and held in trust for the purpose of funding pipeline abandonment in accordance with the CER's regulatory requirements. We had restricted long-term investments held in trust totaling $252 million as at September 30, 2023, which are classified as Level 1 in the fair value hierarchy (December 31, 2022 - $236 million). We also had restricted long-term investments held in trust totaling $383 million (cost basis - $474 million ) and $357 million (cost basis - $437 million ) as at September 30, 2023 and December 31, 2022, respectively, which are classified as Level 2 in the fair value hierarchy. There were unrealized holding losses of $44 million and $7 million on these investments for the three and nine months ended September 30, 2023, respectively (2022 - gains of $11 million and losses of $120 million, respectively). We have wholly-owned captive insurance subsidiaries whose principal activity is providing insurance and reinsurance coverage for certain insurable property and casualty risk exposures of our operating subsidiaries and certain equity investments. As at September 30, 2023, the fair value of investments in equity funds and debt securities held by our captive insurance subsidiaries was $273 million and $353 million, respectively (December 31, 2022 - $335 million and $298 million, respectively). Our investments in debt securities had a cost basis of $346 million as at September 30, 2023 (December 31, 2022 - $295 million). These investments in equity funds and debt securities are recognized at fair value, classified as Level 1 and Level 2 in the fair value hierarchy, respectively, and are recorded in Other current assets and Long-term investments in the Consolidated Statements of Financial Position. There were unrealized holding losses of $8 million and gains of $14 million for the three and nine months ended September 30, 2023, respectively (2022 - losses of $13 million and $40 million, respectively).

INCOME TAXES

INCOME TAXES	9 Months Ended
	Sep. 30, 2023
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES The effective income tax rates for the three months ended September 30, 2023 and 2022 were 17.0% and 18.7%, respectively, and for the nine months ended September 30, 2023 and 2022 was 20.5%. The period-over-period changes in the effective income tax rates are due to an increase in earnings attributable to noncontrolling interests, a decrease in US minimum tax, and the effects of rate-regulated accounting for income taxes, relative to the change in earnings over the comparative periods, offset by the absence of the benefit of a Pennsylvania state corporate tax rate decrease recorded in the three months ended September 30, 2022.

OTHER INCOME_(EXPENSE)

OTHER INCOME/(EXPENSE)	9 Months Ended
	Sep. 30, 2023
Other Income and Expenses [Abstract]
OTHER INCOME/(EXPENSE)	OTHER INCOME/(EXPENSE) Three months ended September 30, Nine months ended September 30, 2023 2022 2023 2022 (millions of Canadian dollars) Gain on dispositions 4 1 15 — Realized foreign currency gain 31 106 177 110 Unrealized foreign currency loss (652) (1,129) (348) (1,345) Net defined pension and OPEB credit 34 59 101 176 Other 118 80 267 135 (465) (883) 212 (924)

CONTINGENCIES

CONTINGENCIES	9 Months Ended
	Sep. 30, 2023
Loss Contingency [Abstract]
CONTINGENCIES	CONTINGENCIES LITIGATION We and our subsidiaries are subject to various legal and regulatory actions and proceedings which arise in the normal course of business, including interventions in regulatory proceedings and challenges 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 will not have a material impact on our interim consolidated financial position or results of operations. AUX SABLE On October 14, 2016, an amended claim was filed against Aux Sable by a counterparty to an NGL supply agreement. On January 5, 2017, Aux Sable filed a Statement of Defence with respect to this claim. On November 27, 2019, the counterparty filed an amended amended claim providing further particulars of its claim against Aux Sable, increasing its damages claimed, and adding defendants Aux Sable Liquid Products Inc. and Aux Sable Extraction LLC (general partners of the previously existing defendants). Aux Sable filed an amended Statement of Defence responding to the amended amended claim on January 31, 2020. During the third quarter of 2023, a provision was recognized in relation to the claim impacting Enbridge's share of earnings from Aux Sable. While the final outcome of this action cannot be predicted with certainty, at this time management believes that the ultimate resolution of this action will not have a material impact on our consolidated financial position or results of operations. TAX MATTERS We and our subsidiaries maintain tax liabilities related to uncertain tax positions. While fully supportable in our view, these tax positions, if challenged by tax authorities, may not be fully sustained on review. INSURANCE We maintain an insurance program for us, our subsidiaries and certain of our affiliates to mitigate a certain portion of our risks. However, not all potential risks arising from our operations are insurable, or are insured by us as a result of availability, high premiums and for various other reasons. We self-insure a significant portion of certain risks through our wholly-owned captive insurance subsidiaries, and our insurance coverage is subject to terms and conditions, exclusions and large deductibles or self-insured retentions which may reduce or eliminate coverage in certain circumstances. Our insurance policies are generally renewed on an annual basis and, depending on factors such as market conditions, the premiums, terms, policy limits and/or deductibles, can vary substantially. We can give no assurance that we will be able to maintain adequate insurance in the future at rates or on other terms we consider commercially reasonable. In such case, we may decide to self-insure additional risks. In the unlikely event multiple insurable incidents occur which exceed coverage limits within the same insurance period, the total insurance coverage will be allocated among entities on an equitable basis based on an insurance allocation agreement we have entered into with us and other subsidiaries. Insurance estimates include certain assumptions and management judgments regarding the frequency and severity of claims, claim development and settlement practices and the selection of estimated loss among estimates derived using different methods.

SUBSEQUENT EVENT

SUBSEQUENT EVENT	9 Months Ended
	Sep. 30, 2023
Subsequent Events [Abstract]
SUBSEQUENT EVENT	SUBSEQUENT EVENTS AITKEN CREEK GAS STORAGE On November 1, 2023, through a wholly-owned Canadian subsidiary, we acquired a 93.8% interest in Aitken Creek Gas Storage Facility and a 100% interest in Aitken Creek North Gas Storage Facility (collectively, Aitken Creek), located in British Columbia, Canada, for $400 million of cash plus payment for derivative contracts and gas inventory, subject to other customary closing adjustments. The acquired assets are included in our Gas Transmission and Midstream segment. HOHE SEE & ALBATROS In November 2023, we signed a definitive agreement to acquire an additional 24.45% interest in the Hohe See Offshore Wind Facilities and Albatros Offshore Wind Facilities (the Offshore Wind Facilities), through the acquisition of a 49% interest in Enbridge Renewable Infrastructure Investments S. à.r.l (ERII), for $391 million (€267 million) of cash and assumed debt of $524 million (€358 million), subject to customary closing adjustments, bringing our interest in the Offshore Wind Facilities to 49.9%. The Hohe See Offshore Wind Facilities and Albatros Offshore Wind Facilities are located approximately 100 kilometers off the northern coast of Germany and came into service in 2019 and 2020, respectively. Subsequent to the purchase, our interest in ERII will be consolidated and our interest in the Offshore Wind Facilities will continue to be accounted for as an equity method investment included in the Renewable Power Generation segment.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Earnings attributable to controlling interests	$ 621	$ 1,362	$ 4,373	$ 3,986

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

REVENUES (Tables)

REVENUES (Tables)	9 Months Ended
	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregation of Revenue	Three months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 2,856 1,294 148 — — — 4,298 Storage and other revenue 65 118 83 — — — 266 Gas distribution revenue — — 528 — — — 528 Electricity revenue — — — 79 — — 79 Total revenue from contracts with customers 2,921 1,412 759 79 — — 5,171 Commodity sales — — — — 4,652 — 4,652 Other revenue 1,2 61 11 (9) (42) — — 21 Intersegment revenue 102 — 1 3 6 (112) — Total revenue 3,084 1,423 751 40 4,658 (112) 9,844 Three months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 2,962 1,264 143 — — — 4,369 Storage and other revenue 58 91 63 — — — 212 Gas distribution revenue — — 699 — — — 699 Electricity revenue — — — 68 — — 68 Total revenue from contracts with customers 3,020 1,355 905 68 — — 5,348 Commodity sales — — — — 6,415 — 6,415 Other revenue 1,2 (258) 10 3 54 — 1 (190) Intersegment revenue 137 1 1 (2) 4 (141) — Total revenue 2,899 1,366 909 120 6,419 (140) 11,573 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 8,800 3,968 593 — — — 13,361 Storage and other revenue 191 326 267 — — — 784 Gas distribution revenue — — 3,611 — — — 3,611 Electricity revenue — — — 220 — — 220 Total revenue from contracts with customers 8,991 4,294 4,471 220 — — 17,976 Commodity sales — — — — 14,114 — 14,114 Other revenue 1,2 170 29 (50) 112 — — 261 Intersegment revenue 358 1 5 2 24 (390) — Total revenue 9,519 4,324 4,426 334 14,138 (390) 32,351 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Transportation revenue 8,212 3,658 551 — — — 12,421 Storage and other revenue 173 258 209 — — — 640 Gas gathering and processing revenue — 21 — — — — 21 Gas distribution revenue — — 3,716 — — — 3,716 Electricity revenue — — — 211 — — 211 Total revenue from contracts with customers 8,385 3,937 4,476 211 — — 17,009 Commodity sales — — — — 22,880 — 22,880 Other revenue 1,2 (225) 28 (30) 222 — 1 (4) Intersegment revenue 432 2 12 (2) 14 (458) — Total revenue 8,592 3,967 4,458 431 22,894 (457) 39,885 1 Includes realized and unrealized gains and losses from our hedging program which for the three months ended September 30, 2023 were a net $97 million loss (2022 - $345 million loss) and for the nine months ended September 30, 2023 were a net $149 million loss (2022 - $483 million loss). 2 Includes revenues from lease contracts for the three months ended September 30, 2023 and 2022 of $107 million and $128 million, respectively, and for the nine months ended September 30, 2023 and 2022 of $387 million and $435 million, respectively. Recognition and Measurement of Revenues Three months ended September 30, 2023 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 38 — 38 Revenues from products and services transferred over time 1 2,921 1,412 721 79 5,133 Total revenue from contracts with customers 2,921 1,412 759 79 5,171 Three months ended September 30, 2022 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 41 — 41 Revenues from products and services transferred over time 1 3,020 1,355 864 68 5,307 Total revenue from contracts with customers 3,020 1,355 905 68 5,348 Nine months ended September 30, 2023 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 105 — 105 Revenues from products and services transferred over time 1 8,991 4,294 4,366 220 17,871 Total revenue from contracts with customers 8,991 4,294 4,471 220 17,976 Nine months ended September 30, 2022 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Consolidated (millions of Canadian dollars) Revenues from products transferred at a point in time — — 77 — 77 Revenues from products and services transferred over time 1 8,385 3,937 4,399 211 16,932 Total revenue from contracts with customers 8,385 3,937 4,476 211 17,009 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.
Schedule of Contract with Customer, Asset and Liability	Contract Balances Contract Receivables Contract Assets Contract Liabilities (millions of Canadian dollars) Balance as at September 30, 2023 2,161 230 2,448 Balance as at December 31, 2022 3,183 230 2,241

SEGMENTED INFORMATION (Tables)

SEGMENTED INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2023
Segment Reporting [Abstract]
Schedule of Reporting Information by Segment	Three months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 3,084 1,423 751 40 4,658 (112) 9,844 Commodity and gas distribution costs — 1 (190) (13) (4,749) 120 (4,831) Operating and administrative (1,088) (578) (305) (63) (10) (11) (2,055) Income/(loss) from equity investments 231 94 — 21 — (3) 343 Other income/(expense) 20 33 15 45 (5) (573) (465) Earnings/(loss) before interest, income taxes and depreciation and amortization 2,247 973 271 30 (106) (579) 2,836 Depreciation and amortization (1,164) Interest expense (921) Income tax expense (128) Earnings 623 Capital expenditures 1 598 989 679 54 — 27 2,347 Three months ended September 30, 2022 Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 2,899 1,366 909 120 6,419 (140) 11,573 Commodity and gas distribution costs 27 — (327) (5) (6,465) 140 (6,630) Operating and administrative (1,173) (545) (311) (58) (9) 7 (2,089) Income from equity investments 193 321 — 22 — — 536 Gain on joint venture merger transaction (Note 5) — 1,076 — — — — 1,076 Other income/(expense) — 33 15 26 (15) (942) (883) Earnings/(loss) before interest, income taxes and depreciation and amortization 1,946 2,251 286 105 (70) (935) 3,583 Depreciation and amortization (1,076) Interest expense (806) Income tax expense (318) Earnings 1,383 Capital expenditures 1 268 525 405 9 — 8 1,215 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 9,519 4,324 4,426 334 14,138 (390) 32,351 Commodity and gas distribution costs — 1 (2,173) (19) (14,179) 392 (15,978) Operating and administrative (3,294) (1,715) (939) (178) (40) 46 (6,120) Income/(loss) from equity investments 733 531 1 83 — (10) 1,338 Other income/(expense) 103 79 39 75 (2) (82) 212 Earnings/(loss) before interest, income taxes and depreciation and amortization 7,061 3,220 1,354 295 (83) (44) 11,803 Depreciation and amortization (3,447) Interest expense (2,709) Income tax expense (1,157) Earnings 4,490 Capital expenditures 1 835 1,332 1,025 77 — 54 3,323 Nine months ended Liquids Pipelines Gas Transmission and Midstream Gas Distribution and Storage Renewable Power Generation Energy Services Eliminations and Other Consolidated (millions of Canadian dollars) Operating revenues 8,592 3,967 4,458 431 22,894 (457) 39,885 Commodity and gas distribution costs — — (2,258) (13) (23,197) 454 (25,014) Operating and administrative (3,096) (1,620) (891) (159) (34) (158) (5,958) Income/(loss) from equity investments 561 877 1 100 — (2) 1,537 Gain on joint venture merger transaction (Note 5) — 1,076 — — — — 1,076 Other income/(expense) 36 84 58 30 (11) (1,121) (924) Earnings/(loss) before interest, income taxes and depreciation and amortization 6,093 4,384 1,368 389 (348) (1,284) 10,602 Depreciation and amortization (3,195) Interest expense (2,316) Income tax expense (1,044) Earnings 4,047 Capital expenditures 1 1,086 1,087 1,005 26 — 32 3,236 1 Includes allowance for equity funds used during construction.

EARNINGS PER COMMON SHARE AND_2

EARNINGS PER COMMON SHARE AND DIVIDENDS PER SHARE (Tables)	9 Months Ended
	Sep. 30, 2023
Earnings Per Share [Abstract]
Schedule of Weighted Average Shares Outstanding Used to Calculate Basic and Diluted Earnings Per Common Share	Weighted average shares outstanding used to calculate basic and diluted earnings per share are as follows: Three months ended Nine months ended 2023 2022 2023 2022 (number of shares in millions) Weighted average shares outstanding 2,048 2,025 2,033 2,026 Effect of dilutive options and RSUs 1 3 2 3 Diluted weighted average shares outstanding 2,049 2,028 2,035 2,029
Schedule of Preferred Stock Characteristics by Class	On October 31, 2023, our Board of Directors declared the following quarterly dividends. All dividends are payable on December 1, 2023 to shareholders of record on November 15, 2023. Dividend per share Common Shares 1 $0.88750 Preference Shares, Series A $0.34375 Preference Shares, Series B $0.32513 Preference Shares, Series D 2 $0.33825 Preference Shares, Series F 3 $0.34613 Preference Shares, Series G 4 $0.47245 Preference Shares, Series H 5 $0.38200 Preference Shares, Series I 6 $0.44814 Preference Shares, Series L US$0.36612 Preference Shares, Series N $0.31788 Preference Shares, Series P $0.27369 Preference Shares, Series R $0.25456 Preference Shares, Series 1 7 US$0.41898 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 8 $0.38825 1 The quarterly dividend per common share was increased 3.2% to $0.8875 from $0.86, effective March 1, 2023. 2 The quarterly dividend per share paid on Preference Shares, Series D was increased to $0.33825 from $0.27875 on March 1, 2023 due to reset of the annual dividend on March 1, 2023. 3 The quarterly dividend per share paid on Preference Shares, Series F was increased to $0.34613 from $0.29306 on June 1, 2023 due to reset of the annual dividend on June 1, 2023. 4 On June 1, 2023, 1,827,695 of the outstanding Preference Shares, Series F were converted into Preference Shares, Series G. The quarterly dividend per share paid on Preference Shares, Series G was increased to $0.47245 from $0.43858 on September 1, 2023 due to reset on a quarterly basis following the date of issuance. 5 The quarterly dividend per share paid on Preference Shares, Series H was increased to $0.38200 from $0.27350 on September 1, 2023 due to reset of the annual dividend on September 1, 2023. 6 On September 1, 2023, 2,350,602 of the outstanding Preference Shares, Series H were converted into Preference Shares, Series I. The first quarterly dividend on Preference Shares, Series I will be paid on December 1, 2023. 7 The quarterly dividend per share paid on Preference Shares, Series 1 was increased to US$0.41898 from US$0.37182 on June 1, 2023 due to reset of the annual dividend on June 1, 2023. 8 The quarterly dividend per share paid on Preference Shares, Series 19 was increased to $0.38825 from $0.30625 on March 1, 2023 due to reset of the annual dividend on March 1, 2023.

ACQUISITION AND DISPOSITIONS (T

ACQUISITION AND DISPOSITIONS (Tables)	9 Months Ended
	Sep. 30, 2023
Business Combination and Asset Acquisition [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the estimated fair values that were assigned to the net assets of TGE: September 27, 2022 (millions of Canadian dollars) Fair value of net assets acquired: Current assets 5 Property, plant and equipment 3 Long-term investments 8 Intangible assets (a) 117 Long-term assets 3 Current liabilities 61 Long-term debt 18 Long-term liabilities (b) 105 Goodwill (c) 392 Purchase price: Cash 295 Contingent consideration (d) 49 344 a) Intangible assets consist of compensation expected to be earned by TGE on existing development contracts once certain project development milestones are met. Fair value was determined using a discounted cash flow method which is an income-based approach to valuation that estimates the present value of future projected benefits from the contracts. The intangible assets will be amortized on a straight-line basis over an expected useful life of three and a half years. b) Long-term liabilities consist primarily of obligations payable to third parties which are contingent on milestones being met for certain projects. Fair value represents the present value of the future cash flow payments at the date of the TGE Acquisition. c) Goodwill is primarily attributable to expected future returns from new opportunities to develop wind and solar projects, as well as enhanced scale and operational diversity of our renewable projects portfolio. The goodwill balance recognized has been assigned to our Renewable Power Generation segment and is tax deductible over 15 years. d) We agreed to pay additional contingent consideration of up to US$53 million to TGE's former common unit holders if performance milestones are met on certain projects. The US$36 million of contingent consideration recognized in the purchase price represents the fair value of contingent consideration at the date of acquisition. The fair value was determined using an income-based approach.

DEBT (Tables)

DEBT (Tables)	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Schedule of Credit Facilities	The following table provides details of our committed credit facilities as at September 30, 2023: Maturity 1 Total Draws 2 Available (millions of Canadian dollars) Enbridge Inc. 2024-2028 8,853 1,272 7,581 Enbridge (U.S.) Inc. 2025-2028 8,585 1,064 7,521 Enbridge Pipelines Inc. 2025 2,000 265 1,735 Enbridge Gas Inc. 2025 2,500 1,585 915 Total committed credit facilities 21,938 4,186 17,752 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.
Schedule of Long-Term Debt Instruments	During the nine months ended September 30, 2023, we completed the following long-term debt issuances totaling US$5.0 billion and $2.9 billion: Company Issue Date Principal Amount (millions of Canadian dollars, unless otherwise stated) Enbridge Inc. March 2023 5.70% sustainability-linked senior notes due March 2033 1 US$2,300 March 2023 5.97% senior notes due March 2026 2 US$700 May 2023 4.90% medium-term notes due May 2028 $600 May 2023 5.36% sustainability-linked medium-term notes due May 2033 3 $400 May 2023 5.76% medium-term notes due May 2053 $500 September 2023 8.50% fixed-to-fixed subordinated notes due January 2084 4 US$1,250 September 2023 8.25 % fixed-to-fixed subordinated notes due January 2084 5 US$750 September 2023 8.75 % fixed-to-fixed subordinated notes due January 2084 6 $700 September 2023 8.50 % fixed-to-fixed subordinated notes due January 2084 7 $300 Enbridge Pipelines Inc. August 2023 5.82% medium-term notes due August 2053 $350 1 The sustainability-linked senior notes are subject to a sustainability performance target of 35% reduction in emissions intensity from 2018 levels at an observation date of December 31, 2030. If the target is not met, on September 8, 2031, the interest rate will be set to equal 5.70% plus 50 basis points. 2 We have the option to call the notes at par after one year from issuance. Refer to Note 8 - Risk Management and Financial Instruments. 3 The sustainability-linked senior notes are subject to a sustainability performance target of 35% reduction in emissions intensity from 2018 levels at an observation date of December 31, 2030. If the target is not met, on November 26, 2031, the interest rate will be set to equal 5.36% plus 50 basis points. 4 For the initial 10 years, the notes carry a fixed interest rate. At year 10, the interest rate will be reset to equal to the Five-Year US Treasury rate plus a margin of 4.43%. Subsequent to year 10, every five years, the Five-year US treasury rate is reset. At year 30, the interest rate will be reset to equal to the Five-Year US Treasury rate plus a margin of 5.18%. 5 For the initial five 6 For the initial 10 years, the notes carry a fixed interest rate. At year 10, the interest rate will be reset to equal to the Five-Year Government of Canada bond yield plus a margin of 4.96%. Subsequent to year 10, every five years, the Government of Canada bond yield rate is reset. At year 30, the interest rate will be reset to equal to the Five-Year Government of Canada bond yield plus a margin of 5.71%. 7 For the initial five
Schedule of Repayment of Debt	During the nine months ended September 30, 2023, we completed the following long-term debt repayments totaling US$1.2 billion and $1.3 billion: Company Repayment Date Principal Amount (millions of Canadian dollars, unless otherwise stated) Enbridge Inc. January 2023 3.94% medium-term notes $275 February 2023 Floating rate notes 1 US$500 April 2023 6.38% fixed-to-floating rate subordinated notes 2 US$600 June 2023 3.94% medium-term notes $450 Enbridge Gas Inc. July 2023 6.05% medium-term notes $100 July 2023 3.79% medium-term notes $250 Enbridge Pipelines (Southern Lights) L.L.C. June 2023 3.98% senior notes US$38 Enbridge Pipelines Inc. August 2023 3.79% medium-term notes $250 Enbridge Southern Lights LP June 2023 4.01% senior notes $9 Tri Global Energy, LLC January 2023 10.00% senior notes US$4 January 2023 14.00% senior notes US$9 1 The notes carried an interest rate set to equal the Secured Overnight Financing Rate plus a margin of 40 basis points. 2 The five-year callable notes, with an original maturity date of April 2078, were all redeemed at par.
Schedule of Amortization of Fair Value Adjustment	Amortization of the fair value adjustment is recorded as a reduction to Interest expense in the Consolidated Statements of Earnings: Three months ended September 30, Nine months ended September 30, 2023 2022 2023 2022 (millions of Canadian dollars) Amortization of fair value adjustment 12 11 34 33

COMPONENTS OF ACCUMULATED OTH_2

COMPONENTS OF ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) (Tables)	9 Months Ended
	Sep. 30, 2023
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Schedule of Changes in AOCI Attributable to Enbridge, Inc. Common Shareholders	Changes in Accumulated other comprehensive income/(loss) (AOCI) attributable to our common shareholders for the nine months ended September 30, 2023 and 2022 are as follows: Cash Excluded Net Cumulative Equity Pension Total (millions of Canadian dollars) Balance as at January 1, 2023 121 (35) (1,137) 4,348 5 218 3,520 Other comprehensive income/(loss) retained in AOCI 447 11 42 (128) 8 — 380 Other comprehensive loss/(income) reclassified to earnings Interest rate contracts 1 63 — — — — — 63 Other contracts 2 1 — — — — — 1 Amortization of pension and OPEB actuarial gain 3 — — — — — (16) (16) 511 11 42 (128) 8 (16) 428 Tax impact Income tax on amounts retained in AOCI (117) — — — (1) — (118) Income tax on amounts reclassified to earnings (6) — — — — 3 (3) (123) — — — (1) 3 (121) Balance as at September 30, 2023 509 (24) (1,095) 4,220 12 205 3,827 Cash Excluded Net Cumulative Equity Pension Total (millions of Canadian dollars) Balance as at January 1, 2022 (897) — (166) 56 (5) (84) (1,096) Other comprehensive income/(loss) retained in AOCI 1,073 (38) (1,187) 5,168 (6) — 5,010 Other comprehensive loss/(income) reclassified to earnings Interest rate contracts 1 187 — — — — — 187 Foreign exchange contracts 4 (4) — — — — — (4) Other contracts 2 3 — — — — — 3 Amortization of pension and OPEB actuarial gain 3 — — — — — (9) (9) Other — — — — 16 — 16 1,259 (38) (1,187) 5,168 10 (9) 5,203 Tax impact Income tax on amounts retained in AOCI (242) — — — (1) — (243) Income tax on amounts reclassified to earnings (41) — — — — 2 (39) (283) — — — (1) 2 (282) Balance as at September 30, 2022 79 (38) (1,353) 5,224 4 (91) 3,825 1 Reported within Interest expense in the Consolidated Statements of Earnings. 2 Reported within Operating and administrative expense in the Consolidated Statements of Earnings. 3 These components are included in the computation of net periodic benefit credit and are reported within Other income/(expense) in the Consolidated Statements of Earnings. 4 Reported within Transportation and other services revenues and Other income/(expense) in the Consolidated Statements of Earnings.

RISK MANAGEMENT AND FINANCIAL_2

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of the Consolidated Statements of Financial Position Location and Carrying Value of Derivative Instruments	The following table summarizes the Consolidated Statements of Financial Position location and carrying value of our derivative instruments, as well as the maximum potential settlement amounts, in the event of the specific circumstances described above. All amounts are presented gross in the Consolidated Statements of Financial Position. September 30, 2023 Derivative Derivative Non- Total Gross Amounts Total Net (millions of Canadian dollars) Other current assets Foreign exchange contracts — 71 32 103 (25) 78 Interest rate contracts 318 — 66 384 (3) 381 Commodity contracts — — 206 206 (153) 53 318 71 304 693 (181) 512 Deferred amounts and other assets Foreign exchange contracts — 31 109 140 (90) 50 Interest rate contracts 130 — 19 149 — 149 Commodity contracts — — 57 57 (36) 21 130 31 185 346 (126) 220 Other current liabilities Foreign exchange contracts — (49) (163) (212) 25 (187) Interest rate contracts — — (3) (3) 3 — Commodity contracts (19) — (343) (362) 153 (209) Other contracts — — (2) (2) — (2) (19) (49) (511) (579) 181 (398) Other long-term liabilities Foreign exchange contracts — (36) (1,004) (1,040) 90 (950) Interest rate contracts (2) — — (2) — (2) Commodity contracts (10) — (166) (176) 36 (140) Other contracts (1) — (1) (2) — (2) (13) (36) (1,171) (1,220) 126 (1,094) Total net derivative asset/(liability) Foreign exchange contracts — 17 (1,026) (1,009) — (1,009) Interest rate contracts 446 — 82 528 — 528 Commodity contracts (29) — (246) (275) — (275) Other contracts (1) — (3) (4) — (4) 416 17 (1,193) (760) — (760) December 31, 2022 Derivative Derivative Non- Total Gross Amounts Total Net (millions of Canadian dollars) Other current assets Foreign exchange contracts — — 46 46 (41) 5 Interest rate contracts 649 — 11 660 — 660 Commodity contracts — — 302 302 (182) 120 Other contracts — — 7 7 — 7 649 — 366 1,015 (223) 792 Deferred amounts and other assets Foreign exchange contracts — 156 153 309 (138) 171 Interest rate contracts 254 — — 254 — 254 Commodity contracts — — 61 61 (25) 36 Other contracts 1 — 2 3 — 3 255 156 216 627 (163) 464 Other current liabilities Foreign exchange contracts — (42) (524) (566) 41 (525) Commodity contracts (48) — (284) (332) 182 (150) (48) (42) (808) (898) 223 (675) Other long-term liabilities Foreign exchange contracts — — (1,116) (1,116) 138 (978) Interest rate contracts (3) — (1) (4) — (4) Commodity contracts (37) — (133) (170) 25 (145) (40) — (1,250) (1,290) 163 (1,127) Total net derivative asset/(liability) Foreign exchange contracts — 114 (1,441) (1,327) — (1,327) Interest rate contracts 900 — 10 910 — 910 Commodity contracts (85) — (54) (139) — (139) Other contracts 1 — 9 10 — 10 816 114 (1,476) (546) — (546)
Schedule of the Maturity and Notional Principal or Quantity Outstanding Related to Derivative Instruments	The following table summarizes the maturity and notional principal or quantity outstanding related to our derivative instruments: September 30, 2023 2023 2024 2025 2026 2027 Thereafter Total Foreign exchange contracts - US dollar forwards - purchase (millions of US dollars) 114 1,000 500 — — — 1,614 Foreign exchange contracts - US dollar forwards - sell (millions of US dollars) 1,593 5,440 4,955 4,325 3,647 2,886 22,846 Foreign exchange contracts - British pound (GBP) forwards - sell (millions of GBP) 7 30 30 28 32 — 127 Foreign exchange contracts - Euro forwards - sell (millions of Euro) 27 91 86 85 81 262 632 Foreign exchange contracts - Japanese yen forwards - purchase (millions of yen) — — 84,800 — — — 84,800 Interest rate contracts - short-term debt pay fixed rate (millions of Canadian dollars) 2,656 5,645 1,364 1,097 75 39 10,876 Interest rate contracts - short-term debt receive fixed rate (millions of Canadian dollars) 229 946 946 179 — — 2,300 Interest rate contracts - long-term debt pay fixed rate (millions of Canadian dollars) 1,726 400 588 — — — 2,714 Interest rate contracts - costless collar (millions of Canadian dollars) — — 394 11 — — 405 Equity contracts (millions of Canadian dollars) — 33 12 — — — 45 Commodity contracts - natural gas (billions of cubic feet) 6 45 27 9 7 — 94 Commodity contracts - crude oil (millions of barrels) 5 (3) — — — — 2 Commodity contracts - power (megawatt per hour) (MW/H) 61 3 (42) (49) (53) (50) (33) 1 1 Total is an average net purchase/(sale) of power.
Schedule of Effect of Cash Flow Hedges and Net Investment Hedges on Consolidated Earnings and Consolidated Comprehensive Income, Before Income Taxes	For foreign exchange derivative instruments that are designated and qualify as fair value hedges, the gain or loss on the derivative is included in Other income/(expense) 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 Other income/(expense) in the Consolidated Statements of Earnings. Any excluded components are included in the Consolidated Statements of Comprehensive Income. Three months ended Nine months ended 2023 2022 2023 2022 (millions of Canadian dollars) Unrealized gain/(loss) on derivative 35 122 (107) 221 Unrealized gain/(loss) on hedged item (35) (122) 106 (211) Realized loss on derivative (11) (5) (34) (101) Realized gain on hedged item — — — 85 The following table presents the effect of cash flow hedges and fair value hedges on our consolidated earnings and consolidated comprehensive income, before the effect of income taxes: Three months ended Nine months ended 2023 2022 2023 2022 (millions of Canadian dollars) Amount of unrealized gain/(loss) recognized in OCI Cash flow hedges Foreign exchange contracts — 1 — 3 Interest rate contracts 313 230 423 1,087 Commodity contracts 20 (16) 56 (27) Other contracts (1) (4) (3) (4) Fair value hedges Foreign exchange contracts 2 (33) 11 (38) 334 178 487 1,021 Amount of loss reclassified from AOCI to earnings Foreign exchange contracts 1 — — — 13 Interest rate contracts 2 40 45 63 187 Commodity contracts 3 1 — — — Other contracts 4 — 1 1 3 41 46 64 203 1 Reported within Transportation and other services revenues and Other income/(expense) in the Consolidated Statements of Earnings. 2 Reported within Interest expense in the Consolidated Statements of Earnings. 3 Reported within Transportation and other services in the Consolidated Statements of Earnings. 4 Reported within Operating and administrative expense in the Consolidated Statements of Earnings.
Schedule of Unrealized Gains and Losses Associated With Changes in the Fair Value of Non-Qualifying Derivatives	The following table presents the unrealized gains and losses associated with changes in the fair value of our non-qualifying derivatives: Three months ended Nine months ended 2023 2022 2023 2022 (millions of Canadian dollars) Foreign exchange contracts 1 (650) (1,379) 415 (1,752) Interest rate contracts 2 17 17 72 1 Commodity contracts 3 (229) 89 (206) 59 Other contracts 4 (3) (3) (11) 1 Total unrealized derivative fair value gain/(loss), net (865) (1,276) 270 (1,691) 1 For the respective nine months ended periods, reported within Transportation and other services revenues (2023 - $645 million gain; 2022 - $375 million loss) and Other income/(expense) (2023 - $230 million loss; 2022 - $1,377 million loss) in the Consolidated Statements of Earnings. 2 Reported as an increase within Interest expense in the Consolidated Statements of Earnings. 3 For the respective nine months ended periods, reported within Transportation and other services revenues (2023 - $85 million loss; 2022 - $12 million gain), Commodity sales (2023 - $75 million gain; 2022 - $151 million gain), Commodity costs (2023 - $136 million loss; 2022 - $116 million loss) and Operating and administrative expense (2023 - $60 million loss; 2022 - $12 million gain) in the Consolidated Statements of Earnings. 4 Reported within Operating and administrative expense in the Consolidated Statements of Earnings.
Schedule of Group Credit Concentrations and Maximum Credit Exposure, With Respect to Derivative Instruments	We have credit concentrations and credit exposure, with respect to derivative instruments, in the following counterparty segments: September 30, December 31, (millions of Canadian dollars) Canadian financial institutions 495 644 US financial institutions 226 277 European financial institutions 123 334 Asian financial institutions 120 224 Other 1 66 105 1,030 1,584 1 Other is comprised of commodity clearing house and physical natural gas and crude oil counterparties.
Schedule of Derivative Assets and Liabilities Measured at Fair Value	We have categorized our derivative assets and liabilities measured at fair value as follows: September 30, 2023 Level 1 Level 2 Level 3 Total Gross (millions of Canadian dollars) Financial assets Current derivative assets Foreign exchange contracts — 103 — 103 Interest rate contracts — 384 — 384 Commodity contracts 58 36 112 206 58 523 112 693 Long-term derivative assets Foreign exchange contracts — 140 — 140 Interest rate contracts — 149 — 149 Commodity contracts — 16 41 57 — 305 41 346 Financial liabilities Current derivative liabilities Foreign exchange contracts — (212) — (212) Interest rate contracts — (3) — (3) Commodity contracts (93) (50) (219) (362) Other contracts — (2) — (2) (93) (267) (219) (579) Long-term derivative liabilities Foreign exchange contracts — (1,040) — (1,040) Interest rate contracts — (2) — (2) Commodity contracts — (20) (156) (176) Other contracts — (2) — (2) — (1,064) (156) (1,220) Total net financial asset/(liability) Foreign exchange contracts — (1,009) — (1,009) Interest rate contracts — 528 — 528 Commodity contracts (35) (18) (222) (275) Other contracts — (4) — (4) (35) (503) (222) (760) December 31, 2022 Level 1 Level 2 Level 3 Total Gross (millions of Canadian dollars) Financial assets Current derivative assets Foreign exchange contracts — 46 — 46 Interest rate contracts — 660 — 660 Commodity contracts 65 90 147 302 Other contracts — 7 — 7 65 803 147 1,015 Long-term derivative assets Foreign exchange contracts — 309 — 309 Interest rate contracts — 254 — 254 Commodity contracts — 17 44 61 Other contracts — 3 — 3 — 583 44 627 Financial liabilities Current derivative liabilities Foreign exchange contracts — (566) — (566) Commodity contracts (60) (77) (195) (332) (60) (643) (195) (898) Long-term derivative liabilities Foreign exchange contracts — (1,116) — (1,116) Interest rate contracts — (4) — (4) Commodity contracts — (38) (132) (170) — (1,158) (132) (1,290) Total net financial asset/(liability) Foreign exchange contracts — (1,327) — (1,327) Interest rate contracts — 910 — 910 Commodity contracts 5 (8) (136) (139) Other contracts — 10 — 10 5 (415) (136) (546)
Schedule of Significant Unobservable Inputs Used in the Fair Value Measurement of Level 3 Derivative Instruments	The significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments were as follows: September 30, 2023 Fair Unobservable Minimum Maximum Weighted Unit of (fair value in millions of Canadian dollars) Commodity contracts - financial 1 Natural gas (20) Forward gas price 1.69 10.93 4.67 $/mmbtu 2 Crude (32) Forward crude price 83.38 120.51 98.08 $/barrel Power (77) Forward power price 30.75 160.92 65.98 $/MW/H Commodity contracts - physical 1 Natural gas (13) Forward gas price 1.58 23.92 5.04 $/mmbtu 2 Crude (19) Forward crude price 84.35 128.65 107.59 $/barrel Power (61) Forward power price 24.47 164.58 61.70 $/MW/H (222) 1 Financial and physical forward commodity contracts are valued using a market approach valuation technique. 2 One million British thermal units (mmbtu).
Schedule of Changes in Net Fair Value of Derivative Assets and Liabilities Classified as Level 3 in the Fair Value Hierarchy	Changes in net fair value of derivative assets and liabilities classified as Level 3 in the fair value hierarchy were as follows: Nine months ended 2023 2022 (millions of Canadian dollars) Level 3 net derivative liability at beginning of period (136) (108) Total gain/(loss) Included in earnings 1 (205) 41 Included in OCI — (28) Settlements 119 (2) Level 3 net derivative liability at end of period (222) (97) 1 Reported within Transportation and other services revenues, Commodity costs and Operating and administrative expense in the Consolidated Statements of Earnings.

OTHER INCOME_(EXPENSE) (Tables)

OTHER INCOME/(EXPENSE) (Tables)	9 Months Ended
	Sep. 30, 2023
Other Income and Expenses [Abstract]
Schedule of Other Income/(Expense)	Three months ended September 30, Nine months ended September 30, 2023 2022 2023 2022 (millions of Canadian dollars) Gain on dispositions 4 1 15 — Realized foreign currency gain 31 106 177 110 Unrealized foreign currency loss (652) (1,129) (348) (1,345) Net defined pension and OPEB credit 34 59 101 176 Other 118 80 267 135 (465) (883) 212 (924)

REVENUES - Disaggregation of Re

REVENUES - Disaggregation of Revenue from Contract with Customers (Details) - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 5,171	$ 5,348	$ 17,976	$ 17,009
Total revenues	9,844	11,573	32,351	39,885
Mark-to-market loss from hedging program	97	345	149	483
Revenues from lease contracts	107	128	387	435
Transportation revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	4,298	4,369	13,361	12,421
Storage and other revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	266	212	784	640
Gas gathering and processing revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers				21
Gas distribution sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	528	699	3,611	3,716
Total revenues	516	695	3,587	3,698
Electricity revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	79	68	220	211
Commodity sales
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	4,652	6,415	14,114	22,880
Total revenues	4,652	6,415	14,114	22,880
Other revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	21	(190)	261	(4)
Liquids Pipelines
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,921	3,020	8,991	8,385
Gas Transmission and Midstream
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,412	1,355	4,294	3,937
Gas Distribution and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	759	905	4,471	4,476
Renewable Power Generation
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	79	68	220	211
Business segments | Liquids Pipelines
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,921	3,020	8,991	8,385
Total revenues	3,084	2,899	9,519	8,592
Business segments | Liquids Pipelines | Transportation revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,856	2,962	8,800	8,212
Business segments | Liquids Pipelines | Storage and other revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	65	58	191	173
Business segments | Liquids Pipelines | Gas gathering and processing revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers				0
Business segments | Liquids Pipelines | Gas distribution sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Liquids Pipelines | Electricity revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Liquids Pipelines | Commodity sales
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	0	0	0
Business segments | Liquids Pipelines | Other revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	61	(258)	170	(225)
Business segments | Gas Transmission and Midstream
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,412	1,355	4,294	3,937
Total revenues	1,423	1,366	4,324	3,967
Business segments | Gas Transmission and Midstream | Transportation revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,294	1,264	3,968	3,658
Business segments | Gas Transmission and Midstream | Storage and other revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	118	91	326	258
Business segments | Gas Transmission and Midstream | Gas gathering and processing revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers				21
Business segments | Gas Transmission and Midstream | Gas distribution sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Gas Transmission and Midstream | Electricity revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Gas Transmission and Midstream | Commodity sales
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	0	0	0
Business segments | Gas Transmission and Midstream | Other revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	11	10	29	28
Business segments | Gas Distribution and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	759	905	4,471	4,476
Total revenues	751	909	4,426	4,458
Business segments | Gas Distribution and Storage | Transportation revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	148	143	593	551
Business segments | Gas Distribution and Storage | Storage and other revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	83	63	267	209
Business segments | Gas Distribution and Storage | Gas gathering and processing revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers				0
Business segments | Gas Distribution and Storage | Gas distribution sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	528	699	3,611	3,716
Business segments | Gas Distribution and Storage | Electricity revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Gas Distribution and Storage | Commodity sales
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	0	0	0
Business segments | Gas Distribution and Storage | Other revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	(9)	3	(50)	(30)
Business segments | Renewable Power Generation
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	79	68	220	211
Total revenues	40	120	334	431
Business segments | Renewable Power Generation | Transportation revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Renewable Power Generation | Storage and other revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Renewable Power Generation | Gas gathering and processing revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers				0
Business segments | Renewable Power Generation | Gas distribution sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Renewable Power Generation | Electricity revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	79	68	220	211
Business segments | Renewable Power Generation | Commodity sales
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	0	0	0
Business segments | Renewable Power Generation | Other revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	(42)	54	112	222
Business segments | Energy Services
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Total revenues	4,658	6,419	14,138	22,894
Business segments | Energy Services | Transportation revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Energy Services | Storage and other revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Energy Services | Gas gathering and processing revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers				0
Business segments | Energy Services | Gas distribution sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Energy Services | Electricity revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Business segments | Energy Services | Commodity sales
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	4,652	6,415	14,114	22,880
Business segments | Energy Services | Other revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	0	0	0
Eliminations and Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Total revenues	(112)	(140)	(390)	(457)
Eliminations and Other | Transportation revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Eliminations and Other | Storage and other revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Eliminations and Other | Gas gathering and processing revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers				0
Eliminations and Other | Gas distribution sales
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Eliminations and Other | Electricity revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Eliminations and Other | Commodity sales
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	0	0	0
Eliminations and Other | Other revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	1	0	1
Intersegment revenue
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	(112)	(141)	(390)	(458)
Total revenues	(112)	(140)	(390)	(457)
Intersegment revenue | Liquids Pipelines
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	102	137	358	432
Intersegment revenue | Gas Transmission and Midstream
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	0	1	1	2
Intersegment revenue | Gas Distribution and Storage
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	1	1	5	12
Intersegment revenue | Renewable Power Generation
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	3	(2)	2	(2)
Intersegment revenue | Energy Services
Disaggregation of Revenue [Line Items]
Revenue not from contract with customers	$ 6	$ 4	$ 24	$ 14

REVENUES - Contract Balances (D

REVENUES - Contract Balances (Details) - CAD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Contract Receivables	$ 2,161	$ 3,183
Contract Assets	230	230
Contract Liabilities	$ 2,448	$ 2,241

REVENUES - Narrative (Details)

REVENUES - Narrative (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2023 CAD ($)	Sep. 30, 2023 CAD ($)
Revenue from Contract with Customer [Abstract]
Revenue recognized	$ 90	$ 179
Increase in contract with customers, liability	213	380
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	57,500	57,500
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 2,000	$ 2,000
Remaining performance obligation, period	3 months	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 6,600	$ 6,600
Remaining performance obligation, period	1 year	1 year

REVENUES - Recognition and Meas

REVENUES - Recognition and Measurement of Revenues (Details) - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 5,171	$ 5,348	$ 17,976	$ 17,009
Revenues from products transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	38	41	105	77
Revenue from products and services transferred over time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	5,133	5,307	17,871	16,932
Liquids Pipelines
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,921	3,020	8,991	8,385
Liquids Pipelines | Revenues from products transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Liquids Pipelines | Revenue from products and services transferred over time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,921	3,020	8,991	8,385
Gas Transmission and Midstream
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,412	1,355	4,294	3,937
Gas Transmission and Midstream | Revenues from products transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Gas Transmission and Midstream | Revenue from products and services transferred over time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,412	1,355	4,294	3,937
Gas Distribution and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	759	905	4,471	4,476
Gas Distribution and Storage | Revenues from products transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	38	41	105	77
Gas Distribution and Storage | Revenue from products and services transferred over time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	721	864	4,366	4,399
Renewable Power Generation
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	79	68	220	211
Renewable Power Generation | Revenues from products transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Renewable Power Generation | Revenue from products and services transferred over time
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 79	$ 68	$ 220	$ 211

SEGMENTED INFORMATION (Details)

SEGMENTED INFORMATION (Details) $ in Millions, $ in Millions			3 Months Ended		9 Months Ended
	Aug. 17, 2022 CAD ($)	Aug. 17, 2022 USD ($)	Sep. 30, 2023 CAD ($)	Sep. 30, 2022 CAD ($)	Sep. 30, 2023 CAD ($)	Sep. 30, 2022 CAD ($)
Segmented Information
Operating revenues			$ 9,844	$ 11,573	$ 32,351	$ 39,885
Commodity and gas distribution costs			(4,831)	(6,630)	(15,978)	(25,014)
Operating and administrative			(2,055)	(2,089)	(6,120)	(5,958)
Income/(loss) from equity investments			343	536	1,338	1,537
Gain on joint venture merger transaction	$ 1,100	$ 832	0	1,076	0	1,076
Other income/(expense)			(465)	(883)	212	(924)
Earnings/(loss) before interest, income taxes and depreciation and amortization			2,836	3,583	11,803	10,602
Depreciation and amortization			(1,164)	(1,076)	(3,447)	(3,195)
Interest expense			(921)	(806)	(2,709)	(2,316)
Income tax expense			(128)	(318)	(1,157)	(1,044)
Earnings			623	1,383	4,490	4,047
Capital expenditures			2,347	1,215	3,323	3,236
Eliminations and Other
Segmented Information
Operating revenues			(112)	(140)	(390)	(457)
Commodity and gas distribution costs			120	140	392	454
Operating and administrative			(11)	7	46	(158)
Income/(loss) from equity investments			(3)	0	(10)	(2)
Gain on joint venture merger transaction				0		0
Other income/(expense)			(573)	(942)	(82)	(1,121)
Earnings/(loss) before interest, income taxes and depreciation and amortization			(579)	(935)	(44)	(1,284)
Capital expenditures			27	8	54	32
Liquids Pipelines | Business segments
Segmented Information
Operating revenues			3,084	2,899	9,519	8,592
Commodity and gas distribution costs			0	27	0	0
Operating and administrative			(1,088)	(1,173)	(3,294)	(3,096)
Income/(loss) from equity investments			231	193	733	561
Gain on joint venture merger transaction				0		0
Other income/(expense)			20	0	103	36
Earnings/(loss) before interest, income taxes and depreciation and amortization			2,247	1,946	7,061	6,093
Capital expenditures			598	268	835	1,086
Gas Transmission and Midstream | Business segments
Segmented Information
Operating revenues			1,423	1,366	4,324	3,967
Commodity and gas distribution costs			1	0	1	0
Operating and administrative			(578)	(545)	(1,715)	(1,620)
Income/(loss) from equity investments			94	321	531	877
Gain on joint venture merger transaction				1,076		1,076
Other income/(expense)			33	33	79	84
Earnings/(loss) before interest, income taxes and depreciation and amortization			973	2,251	3,220	4,384
Capital expenditures			989	525	1,332	1,087
Gas Distribution and Storage | Business segments
Segmented Information
Operating revenues			751	909	4,426	4,458
Commodity and gas distribution costs			(190)	(327)	(2,173)	(2,258)
Operating and administrative			(305)	(311)	(939)	(891)
Income/(loss) from equity investments			0	0	1	1
Gain on joint venture merger transaction				0		0
Other income/(expense)			15	15	39	58
Earnings/(loss) before interest, income taxes and depreciation and amortization			271	286	1,354	1,368
Capital expenditures			679	405	1,025	1,005
Renewable Power Generation | Business segments
Segmented Information
Operating revenues			40	120	334	431
Commodity and gas distribution costs			(13)	(5)	(19)	(13)
Operating and administrative			(63)	(58)	(178)	(159)
Income/(loss) from equity investments			21	22	83	100
Gain on joint venture merger transaction				0		0
Other income/(expense)			45	26	75	30
Earnings/(loss) before interest, income taxes and depreciation and amortization			30	105	295	389
Capital expenditures			54	9	77	26
Energy Services | Business segments
Segmented Information
Operating revenues			4,658	6,419	14,138	22,894
Commodity and gas distribution costs			(4,749)	(6,465)	(14,179)	(23,197)
Operating and administrative			(10)	(9)	(40)	(34)
Income/(loss) from equity investments			0	0	0	0
Gain on joint venture merger transaction				0		0
Other income/(expense)			(5)	(15)	(2)	(11)
Earnings/(loss) before interest, income taxes and depreciation and amortization			(106)	(70)	(83)	(348)
Capital expenditures			$ 0	$ 0	$ 0	$ 0

EARNINGS PER COMMON SHARE AND_3

EARNINGS PER COMMON SHARE AND DIVIDENDS PER SHARE - Diluted (Details) - $ / shares shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Weighted average number of common shares outstanding diluted
Weighted average shares outstanding (in shares)	2,048	2,025	2,033	2,026
Effect of dilutive options and RSUs (in shares)	1	3	2	3
Diluted weighted average shares outstanding (in shares)	2,049	2,028	2,035	2,029
Stock options
Weighted average number of common shares outstanding diluted
Antidilutive securities excluded from the diluted earnings per common share calculation (in shares)	21.6	11.4	18.2	9.2
Weighted average exercise price of antidilutive securities (in Canadian dollars per share)	$ 53.69	$ 56.49	$ 54.81	$ 56.63

EARNINGS PER COMMON SHARE AND_4

EARNINGS PER COMMON SHARE AND DIVIDENDS PER SHARE - Dividends Per Share (Details)

1 Months Ended

3 Months Ended

9 Months Ended

Dec. 01, 2023 $ / shares

Dec. 01, 2023 $ / shares

Oct. 31, 2023 $ / shares

Oct. 31, 2023 $ / shares

Sep. 01, 2023 $ / shares shares

Aug. 31, 2023 $ / shares

Jun. 01, 2023 $ / shares shares

Jun. 01, 2023 $ / shares shares

May 31, 2023 $ / shares

May 31, 2023 $ / shares

Mar. 01, 2023

Feb. 28, 2023 $ / shares

Mar. 31, 2023 $ / shares

Sep. 30, 2023 $ / shares

Sep. 30, 2022 $ / shares

Sep. 30, 2023 $ / shares

Sep. 30, 2022 $ / shares

Dividends Payable [Line Items]

Common stock, dividends per share, paid (dollars per share)

$ 0.89

$ 0.86

$ 2.67

$ 2.58

Common stock dividends increased (in percent)

3.20%

Common shares

Dividends Payable [Line Items]

Common stock, dividends, per share, declared (dollars per share)

$ 0.86

$ 0.8875

Common shares | Forecast

Dividends Payable [Line Items]

Common stock, dividends per share, paid (dollars per share)

$ 0.88750

Common shares | Subsequent event

Dividends Payable [Line Items]

Common stock, dividends, per share, declared (dollars per share)

$ 0.88750

Preferred share investment

Dividends Payable [Line Items]

Number of Series F preference shares converted into Series G preference shares( in shares) | shares

2,350,602

1,827,695

1,827,695

Preferred share investment | Preference Shares, Series A | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.34375

Preferred share investment | Preference Shares, Series A | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.34375

Preferred share investment | Preference Shares, Series B | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.32513

Preferred share investment | Preference Shares, Series B | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.32513

Preferred share investment | Preference Shares, Series D2

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.27875

0.33825

Preferred share investment | Preference Shares, Series D2 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.33825

Preferred share investment | Preference Shares, Series D2 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.33825

Preferred share investment | Preference Shares, Series F

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.34613

$ 0.29306

Preferred share investment | Preference Shares, Series F | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.34613

Preferred share investment | Preference Shares, Series F | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.34613

Preferred share investment | Preference Shares, Series G

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.47245

$ 0.43858

Preferred share investment | Preference Shares, Series G | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.47245

Preferred share investment | Preference Shares, Series G | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.47245

Preferred share investment | Preference Shares, Series H5

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.38200

$ 0.27350

Preferred share investment | Preference Shares, Series H5 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.38200

Preferred share investment | Preference Shares, Series H5 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.38200

Preferred share investment | Preference Shares, Series L | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

$ 0.36612

Preferred share investment | Preference Shares, Series L | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.36612

Preferred share investment | Preference Shares, Series N | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.31788

Preferred share investment | Preference Shares, Series N | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.31788

Preferred share investment | Preference Shares, Series P | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.27369

Preferred share investment | Preference Shares, Series P | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.27369

Preferred share investment | Preference Shares, Series R | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.25456

Preferred share investment | Preference Shares, Series R | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.25456

Preferred share investment | Preference Shares, Series 1

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.41898

$ 0.37182

Preferred share investment | Preference Shares, Series 1 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.41898

Preferred share investment | Preference Shares, Series 1 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.41898

Preferred share investment | Preference Shares, Series 3 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.23356

Preferred share investment | Preference Shares, Series 3 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.23356

Preferred share investment | Preference Shares, Series 5 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

$ 0.33596

Preferred share investment | Preference Shares, Series 5 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.33596

Preferred share investment | Preference Shares, Series 7 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.27806

Preferred share investment | Preference Shares, Series 7 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.27806

Preferred share investment | Preference Shares, Series 9 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.25606

Preferred share investment | Preference Shares, Series 9 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.25606

Preferred share investment | Preference Shares, Series 11 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.24613

Preferred share investment | Preference Shares, Series 11 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.24613

Preferred share investment | Preference Shares, Series 13 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.19019

Preferred share investment | Preference Shares, Series 13 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.19019

Preferred share investment | Preference Shares, Series 15 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.18644

Preferred share investment | Preference Shares, Series 15 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.18644

Preferred share investment | Preference Shares, Series 198

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.30625

$ 0.38825

Preferred share investment | Preference Shares, Series 198 | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

0.38825

Preferred share investment | Preference Shares, Series 198 | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

0.38825

Preferred share investment | Series I Preferred Stock | Forecast

Dividends Payable [Line Items]

Preferred stock, dividend declared per share (dollars per share)

$ 0.44814

Preferred share investment | Series I Preferred Stock | Subsequent event

Dividends Payable [Line Items]

Preferred stock, dividend paid per share (dollars per share)

$ 0.44814

ACQUISITION AND DISPOSITIONS -

ACQUISITION AND DISPOSITIONS - Narrative (Details) $ / shares in Units, $ in Millions, $ in Millions										1 Months Ended		3 Months Ended		9 Months Ended
	Sep. 08, 2023 CAD ($) $ / shares shares	Sep. 05, 2023 CAD ($)	Sep. 05, 2023 USD ($)	Apr. 03, 2023 CAD ($)	Apr. 03, 2023 USD ($)	Sep. 27, 2022 CAD ($)	Sep. 27, 2022 USD ($)	Aug. 17, 2022 CAD ($)	Aug. 17, 2022 USD ($)	Sep. 30, 2023 CAD ($) offering	Sep. 30, 2023 USD ($) offering	Sep. 30, 2023 CAD ($) offering	Sep. 30, 2022 CAD ($)	Sep. 30, 2023 CAD ($) offering	Sep. 30, 2022 CAD ($)	Apr. 03, 2023 USD ($)	Oct. 05, 2022 CAD ($)	Sep. 28, 2022 pipeline _community	Sep. 27, 2022 USD ($)	Aug. 16, 2022
Business Acquisition [Line Items]
Proceeds from sale of equity method investments								$ 522	$ 404					$ 0	$ 522
Gain on joint venture merger transaction								$ 1,100	$ 832			$ 0	$ 1,076	0	$ 1,076
Public Offering
Business Acquisition [Line Items]
Public offering common shares (in shares) | shares	102,913,500
Offering price per share ( in cad per share) | $ / shares	$ 44.7
Proceeds of common shares value	$ 4,600													$ 4,600
Private Placement
Business Acquisition [Line Items]
Sale of stock, number of offerings | offering										2	2	2		2
Private Placement, One
Business Acquisition [Line Items]
Sale of stock, consideration received on transaction											$ 2,000
Private Placement, Two
Business Acquisition [Line Items]
Sale of stock, consideration received on transaction										$ 1,000
Athabasca Indigenous Investments Limited Partnership
Business Acquisition [Line Items]
Number of communities represented | _community																		23
Athabasca Regional Oil Sands System
Business Acquisition [Line Items]
Number of pipelines to be sold | pipeline																		7
Total consideration																	$ 1,100
Gray Oak Holdings LLC
Business Acquisition [Line Items]
Ownership interest (in percent)								58.50%	58.50%											22.80%
DCP LLC
Business Acquisition [Line Items]
Ownership interest (in percent)								13.20%	13.20%											28.30%
Athabasca Regional Oil Sands System | Athabasca Regional Oil Sands System
Business Acquisition [Line Items]
Non-operating interest (percent)																		11.60%
Noncontrolling interest (percent)																		88.40%
The East Ohio Gas Company, Questar Gas Company, And Wexpro Companies
Business Acquisition [Line Items]
Purchase price		$ 19,100	$ 14,000
Cash consideration		12,800	9,400
Assumed debt		$ 6,300	$ 4,600
Tres Palacios Holdings LLC
Business Acquisition [Line Items]
Cash consideration				$ 451	$ 335
Property, plant and equipment				790												$ 588
Cavern right-of-use assets				254												189
Current portion of long-term debt				7												5
Long-term debt				$ 248												$ 184
Tri Global Energy, LLC
Business Acquisition [Line Items]
Purchase price						$ 344
Cash consideration						295	$ 215
Property, plant and equipment						3
Long-term debt						18
Business combination, additional contingent consideration (up to)						$ 72													$ 53

ACQUISITIONS AND DISPOSITIONS -

ACQUISITIONS AND DISPOSITIONS - Summary of Estimated Fair Values Assigned to Net Assets (Details) $ in Millions, $ in Millions	Sep. 27, 2022 CAD ($)	Sep. 27, 2022 USD ($)	Sep. 30, 2023 CAD ($)	Dec. 31, 2022 CAD ($)	Sep. 27, 2022 USD ($)
Business Acquisition [Line Items]
Goodwill			$ 32,390	$ 32,440
TRI GLOBAL ENERGY, LLC
Business Acquisition [Line Items]
Current assets	$ 5
Property, plant and equipment	3
Long-term investments	8
Intangible assets	117
Long-term assets	3
Current liabilities	61
Long-term debt	18
Long-term liabilities	105
Goodwill	392
Purchase price:
Cash	295	$ 215
Contingent consideration	49				$ 36
Purchase price	$ 344
Expected useful life	3 years 6 months				3 years 6 months
Goodwill expected tax deductible period	15 years	15 years
Business combination, additional contingent consideration (up to)	$ 72				$ 53

DEBT - Credit Facilities (Detai

DEBT - Credit Facilities (Details) - Committed credit facilities $ in Millions	9 Months Ended
	Sep. 30, 2023 CAD ($)
CREDIT FACILITIES
Total Facilities	$ 21,938
Draws	4,186
Available	$ 17,752
Term out option period	1 year
Enbridge (U.S.) Inc.
CREDIT FACILITIES
Total Facilities	$ 8,585
Draws	1,064
Available	7,521
Enbridge Pipelines Inc.
CREDIT FACILITIES
Total Facilities	2,000
Draws	265
Available	1,735
Enbridge Gas Inc.
CREDIT FACILITIES
Total Facilities	2,500
Draws	1,585
Available	915
Enbridge Inc.
CREDIT FACILITIES
Total Facilities	8,853
Draws	1,272
Available	$ 7,581

DEBT - Narrative (Details)

DEBT - Narrative (Details) $ in Millions, $ in Billions		1 Months Ended			9 Months Ended
	Sep. 08, 2023 CAD ($)	Oct. 31, 2023 CAD ($) offer	Jul. 31, 2023 CAD ($)	Mar. 31, 2023 CAD ($)	Sep. 30, 2023 CAD ($)	Sep. 30, 2023 USD ($)	Feb. 28, 2023 CAD ($)	Dec. 31, 2022 CAD ($)
Line of Credit Facility [Line Items]
Commitment fee percentage					0.10%
Long-term debt					$ 68,793			$ 72,939
Long-term debt, fair value adjustment					551			608
Public Offering
Line of Credit Facility [Line Items]
Proceeds of common shares value	$ 4,600				4,600
Commercial paper and credit facility draws
Line of Credit Facility [Line Items]
Long-term debt					2,100			10,500
Fixed-to-floating subordinated term notes | Subordinated term notes
Line of Credit Facility [Line Items]
Subordinated debt					13,200			10,300
Enbridge Gas Inc. | Subsequent event
Line of Credit Facility [Line Items]
Number of offering | offer		3
Principal amount of debt		$ 1,000
Enbridge Gas Inc. | Five-year medium term notes | Subsequent event
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)		5 years
Enbridge Gas Inc. | 10-year medium term notes | Subsequent event
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)		10 years
Enbridge Gas Inc. | 30-year medium term notes | Subsequent event
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)		30 years
Committed credit facilities
Line of Credit Facility [Line Items]
Amount of credit facility					$ 21,938
Term out option period					1 year
Unutilized amount of facility					$ 17,752
Committed credit facilities | Senior Unsecured Bridge Term Loan
Line of Credit Facility [Line Items]
Amount of credit facility						$ 9.4
Unutilized amount of facility						$ 3.4
Committed credit facilities | Enbridge Gas Inc.
Line of Credit Facility [Line Items]
Amount of credit facility					2,500
Unutilized amount of facility					915
Committed credit facilities | Enbridge Gas Inc. | 364-day extendible credit facility
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)				364 days
Amount of credit facility				$ 2,500			$ 2,000
Term out option period				1 year
Committed credit facilities | Enbridge Pipelines Inc.
Line of Credit Facility [Line Items]
Amount of credit facility					2,000
Unutilized amount of facility					1,735
Committed credit facilities | Enbridge Pipelines Inc. | 364-day extendible credit facility
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)			364 days
Term out option period			1 year
Revolving credit facility | 364-day extendible credit facility
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)			364 days
Amount of credit facility			$ 6,800
Term out option period			1 year
Revolving credit facility | Sustainability-linked Credit Facility
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)			5 years
Amount of credit facility			$ 7,600
Revolving credit facility | Term Loan Maturing In July 2026
Line of Credit Facility [Line Items]
Debt instrument maturity period (in year)			3 years
Uncommitted demand credit facilities
Line of Credit Facility [Line Items]
Amount of credit facility					1,300			1,300
Unutilized amount of facility					$ 712			$ 689

DEBT - Long Term Debt Issuance

DEBT - Long Term Debt Issuance (Details) $ in Millions, $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2023 CAD ($)	Aug. 31, 2023 CAD ($)	Sep. 30, 2022
Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt	$ 5,000	$ 2,900
5.70% sustainability-linked senior notes due March 2033 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt	$ 2,300
Interest rate (as a percent)	5.70%	5.70%
5.70% sustainability-linked senior notes due March 2033 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period One
Debt Instrument [Line Items]
Sustainability performance target (percent)	35%	35%
5.70% sustainability-linked senior notes due March 2033 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Two
Debt Instrument [Line Items]
Interest rate (as a percent)	5.70%	5.70%
Spread on variable rate (percent)	0.50%
5.97% senior notes due March 2026 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt	$ 700
Interest rate (as a percent)	5.97%	5.97%
Debt instrument maturity period (in year)	1 year
4.90% medium-notes due may 2028 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt		$ 600
Interest rate (as a percent)	4.90%	4.90%
5.36% sustainability-linked senior notes due May 2033 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt		$ 400
Interest rate (as a percent)	5.36%	5.36%
5.36% sustainability-linked senior notes due May 2033 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period One
Debt Instrument [Line Items]
Sustainability performance target (percent)	35%	35%
5.36% sustainability-linked senior notes due May 2033 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Two
Debt Instrument [Line Items]
Interest rate (as a percent)	5.36%	5.36%
Spread on variable rate (percent)	0.50%
5.76% medium notes due may 2053 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt		$ 500
Interest rate (as a percent)	5.76%	5.76%
8.50% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt	$ 1,250
Interest rate (as a percent)				8.50%
8.50% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Term of fixed rate	10 years
8.50% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period One | 5-year United States Treasury rate | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	4.43%
8.50% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Two | 5-year United States Treasury rate | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	5.18%
8.25% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt	$ 750
Interest rate (as a percent)	8.25%	8.25%
8.25% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Term of fixed rate	5 years
8.25% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period One | 5-year United States Treasury rate | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	3.79%
8.25% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Two | 5-year United States Treasury rate | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	4.04%
8.25% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Three | 5-year United States Treasury rate | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	4.79%
8.75% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt		$ 700
Interest rate (as a percent)	8.75%	8.75%
8.75% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Term of fixed rate	10 years
8.75% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period One | Government Of Canada Bond Yield | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	4.96%
8.75% fixed-to-fixed subordinated notes due january 2084 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Two | Government Of Canada Bond Yield | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	5.71%
8.50% fixed-to-fixed subordinated notes due january 2084-1 | Enbridge Inc.
Debt Instrument [Line Items]
Principal amount of debt		$ 300
Interest rate (as a percent)	8.50%	8.50%
8.50% fixed-to-fixed subordinated notes due january 2084-1 | Enbridge Inc. | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Term of fixed rate	5 years
8.50% fixed-to-fixed subordinated notes due january 2084-1 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period One | Government Of Canada Bond Yield | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	4.30%
8.50% fixed-to-fixed subordinated notes due january 2084-1 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Two | Government Of Canada Bond Yield | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	4.55%
8.50% fixed-to-fixed subordinated notes due january 2084-1 | Enbridge Inc. | Debt Instrument Interest Rate Terms Period Three | Government Of Canada Bond Yield | Fixed To Fixed Term Subordinated Term Notes
Debt Instrument [Line Items]
Spread on variable rate (percent)	5.30%
Medium-term notes due august 2053 | Enbridge Pipelines Inc.
Debt Instrument [Line Items]
Principal amount of debt			$ 350
Interest rate (as a percent)			5.82%

DEBT - Long Term Debt Repayment

DEBT - Long Term Debt Repayments (Details) $ in Millions, $ in Millions	1 Months Ended								9 Months Ended
	Aug. 31, 2023 CAD ($)	Jul. 31, 2023 CAD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2023 CAD ($)	Apr. 30, 2023 USD ($)	Feb. 28, 2023 USD ($)	Jan. 31, 2023 USD ($)	Jan. 31, 2023 CAD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2023 CAD ($)
Long-Term Debt
DEBT
Principal Amount									$ 1,200	$ 1,300
6.05 medium term notes | Enbridge Gas Inc.
DEBT
Interest rate (as a percent)		6.05%
Principal Amount		$ 100
3.79 medium term notes | Enbridge Pipelines Inc.
DEBT
Interest rate (as a percent)	3.79%
Principal Amount	$ 250
3.79 medium term notes | Enbridge Gas Inc.
DEBT
Interest rate (as a percent)		3.79%
Principal Amount		$ 250
3.98% senior notes due June 2022 | Enbridge Pipelines (Southern Lights) L.L.C.
DEBT
Interest rate (as a percent)			3.98%	3.98%
Principal Amount			$ 38
4.01% senior notes | Enbridge Southern Lights LP
DEBT
Interest rate (as a percent)			4.01%	4.01%
Principal Amount				$ 9
10.00% Senior notes | Tri Global Energy, LLC
DEBT
Interest rate (as a percent)							10%	10%
Principal Amount							$ 4
14.00% Senior notes | Tri Global Energy, LLC
DEBT
Interest rate (as a percent)							14%	14%
Principal Amount							$ 9
Enbridge Inc. | 3.94% medium-term notes
DEBT
Interest rate (as a percent)			3.94%	3.94%			3.94%	3.94%
Principal Amount				$ 450				$ 275
Enbridge Inc. | Floating rate notes
DEBT
Principal Amount						$ 500
Enbridge Inc. | Floating rate notes | London Interbank Offered Rate
DEBT
Spread on variable rate (percent)									0.40%	0.40%
Enbridge Inc. | 6.38% fixed-to-floating rate subordinated notes
DEBT
Interest rate (as a percent)					6.38%
Principal Amount					$ 600

DEBT - Fair Value Adjustment (D

DEBT - Fair Value Adjustment (Details) - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Debt Disclosure [Abstract]
Amortization of fair value adjustment	$ 12	$ 11	$ 34	$ 33

COMPONENTS OF ACCUMULATED OTH_3

COMPONENTS OF ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) (Details) - CAD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Changes in AOCI
Balance at the beginning of the period	$ 63,398
Other comprehensive income/(loss) retained in AOCI	380	$ 5,010
Other		16
Total before tax impact	428	5,203
Income tax on amounts retained in AOCI	(118)	(243)
Income tax on amounts reclassified to earnings	(3)	(39)
Tax impact	(121)	(282)
Balance at the end of the period	68,474	67,430
Interest rate contracts
Changes in AOCI
Other comprehensive loss/(income) reclassified to earnings	63	187
Foreign exchange contracts
Changes in AOCI
Other comprehensive loss/(income) reclassified to earnings		(4)
Other contracts
Changes in AOCI
Other comprehensive loss/(income) reclassified to earnings	1	3
Total
Changes in AOCI
Balance at the beginning of the period	3,520	(1,096)
Balance at the end of the period	3,827	3,825
Cash Flow Hedges
Changes in AOCI
Balance at the beginning of the period	121	(897)
Other comprehensive income/(loss) retained in AOCI	447	1,073
Total before tax impact	511	1,259
Income tax on amounts retained in AOCI	(117)	(242)
Income tax on amounts reclassified to earnings	(6)	(41)
Tax impact	(123)	(283)
Balance at the end of the period	509	79
Cash Flow Hedges | Interest rate contracts
Changes in AOCI
Other comprehensive loss/(income) reclassified to earnings	63	187
Cash Flow Hedges | Foreign exchange contracts
Changes in AOCI
Other comprehensive loss/(income) reclassified to earnings		(4)
Cash Flow Hedges | Other contracts
Changes in AOCI
Other comprehensive loss/(income) reclassified to earnings	1	3
Excluded Components of Fair Value Hedges
Changes in AOCI
Balance at the beginning of the period	(35)	0
Other comprehensive income/(loss) retained in AOCI	11	(38)
Total before tax impact	11	(38)
Tax impact	0	0
Balance at the end of the period	(24)	(38)
Net Investment Hedges
Changes in AOCI
Balance at the beginning of the period	(1,137)	(166)
Other comprehensive income/(loss) retained in AOCI	42	(1,187)
Total before tax impact	42	(1,187)
Income tax on amounts retained in AOCI		0
Tax impact	0	0
Balance at the end of the period	(1,095)	(1,353)
Cumulative Translation Adjustment
Changes in AOCI
Balance at the beginning of the period	4,348	56
Other comprehensive income/(loss) retained in AOCI	(128)	5,168
Total before tax impact	(128)	5,168
Tax impact	0	0
Balance at the end of the period	4,220	5,224
Equity Investees
Changes in AOCI
Balance at the beginning of the period	5	(5)
Other comprehensive income/(loss) retained in AOCI	8	(6)
Other		16
Total before tax impact	8	10
Income tax on amounts retained in AOCI	(1)	(1)
Tax impact	(1)	(1)
Balance at the end of the period	12	4
Pension and OPEB Adjustment
Changes in AOCI
Balance at the beginning of the period	218	(84)
Other comprehensive loss/(income) reclassified to earnings	(16)	(9)
Total before tax impact	(16)	(9)
Income tax on amounts reclassified to earnings	3	2
Tax impact	3	2
Balance at the end of the period	$ 205	$ (91)

RISK MANAGEMENT AND FINANCIAL_3

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Foreign Exchange Risk (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 CAD ($)
Foreign exchange contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Derivatives terminated, realized loss	$ 638

RISK MANAGEMENT AND FINANCIAL_4

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Market Risk (Details) $ in Millions		9 Months Ended
	Mar. 08, 2023 USD ($)	Sep. 30, 2023 equity_type
Three-Year Fixed Rate Notes | Notes Payable, Other Payables
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
Principal Amount | $	$ 700
Debt instrument maturity period (in year)	3 years
Interest rate contracts - short-term borrowings
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
Floating rate debt as target percentage of total debt outstanding maximum		30%
Average swap rate (percent)		4.20%
Derivative, fixed interest rate	6%
Floating-To-Fixed interest rate swaps
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
Average swap rate (percent)		2.70%
Equity contracts
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
Number of forms of stock-based compensation with equity price risk | equity_type		1

RISK MANAGEMENT AND FINANCIAL_5

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Total Derivative Instruments (Details) - CAD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	$ (760)	$ (546)
Derivative liabilities, Total Net Derivative Instruments	(760)	(546)
Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(1,193)	(1,476)
Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	416	816
Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	17	114
Other current assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	693	1,015
Derivative assets, Amounts Available for Offset	(181)	(223)
Derivative assets, Total Net Derivative Instruments	512	792
Other current assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	304	366
Other current assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	318	649
Other current assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	71	0
Deferred amounts and other assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	346	627
Derivative assets, Amounts Available for Offset	(126)	(163)
Derivative assets, Total Net Derivative Instruments	220	464
Deferred amounts and other assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	185	216
Deferred amounts and other assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	130	255
Deferred amounts and other assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	31	156
Other current liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(579)	(898)
Derivative liabilities, Amounts Available for Offset	181	223
Derivative liabilities, Total Net Derivative Instruments	(398)	(675)
Other current liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(511)	(808)
Other current liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(19)	(48)
Other current liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(49)	(42)
Other long-term liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(1,220)	(1,290)
Derivative liabilities, Amounts Available for Offset	126	163
Derivative liabilities, Total Net Derivative Instruments	(1,094)	(1,127)
Other long-term liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(1,171)	(1,250)
Other long-term liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(13)	(40)
Other long-term liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(36)	0
Foreign exchange contracts
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(1,009)	(1,327)
Derivative liabilities, Total Net Derivative Instruments	(1,009)	(1,327)
Foreign exchange contracts | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(1,026)	(1,441)
Foreign exchange contracts | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	0	$ 0
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Other Liabilities, Noncurrent
Foreign exchange contracts | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	17	$ 114
Foreign exchange contracts | Other current assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	103	46
Derivative assets, Amounts Available for Offset	(25)	(41)
Derivative assets, Total Net Derivative Instruments	78	5
Foreign exchange contracts | Other current assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	32	46
Foreign exchange contracts | Other current assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Foreign exchange contracts | Other current assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	71	0
Foreign exchange contracts | Deferred amounts and other assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	140	309
Derivative assets, Amounts Available for Offset	(90)	(138)
Derivative assets, Total Net Derivative Instruments	50	171
Foreign exchange contracts | Deferred amounts and other assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	109	153
Foreign exchange contracts | Deferred amounts and other assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Foreign exchange contracts | Deferred amounts and other assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	31	156
Foreign exchange contracts | Other current liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(212)	(566)
Derivative liabilities, Amounts Available for Offset	25	41
Derivative liabilities, Total Net Derivative Instruments	(187)	(525)
Foreign exchange contracts | Other current liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(163)	(524)
Foreign exchange contracts | Other current liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0	0
Foreign exchange contracts | Other current liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(49)	(42)
Foreign exchange contracts | Other long-term liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(1,040)	(1,116)
Derivative liabilities, Amounts Available for Offset	90	138
Derivative liabilities, Total Net Derivative Instruments	(950)	(978)
Foreign exchange contracts | Other long-term liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(1,004)	(1,116)
Foreign exchange contracts | Other long-term liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0	0
Foreign exchange contracts | Other long-term liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(36)	0
Interest rate contracts
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities		(4)
Total net financial asset/(liability)	528	910
Derivative assets, Total Net Derivative Instruments	528	$ 910
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Other Liabilities, Noncurrent
Interest rate contracts | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities		$ (1)
Total net financial asset/(liability)	82	$ 10
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Other Liabilities, Noncurrent
Interest rate contracts | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities		$ (3)
Total net financial asset/(liability)	446	900
Interest rate contracts | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities		0
Total net financial asset/(liability)	0	$ 0
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Other Liabilities, Noncurrent
Interest rate contracts | Other current assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	384	$ 660
Derivative assets, Amounts Available for Offset	(3)	0
Derivative assets, Total Net Derivative Instruments	381	660
Interest rate contracts | Other current assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	66	11
Interest rate contracts | Other current assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	318	649
Interest rate contracts | Other current assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Interest rate contracts | Deferred amounts and other assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	149	254
Derivative assets, Amounts Available for Offset	0	0
Derivative assets, Total Net Derivative Instruments	149	254
Interest rate contracts | Deferred amounts and other assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	19	0
Interest rate contracts | Deferred amounts and other assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	130	254
Interest rate contracts | Deferred amounts and other assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Interest rate contracts | Other current liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(3)
Derivative liabilities, Amounts Available for Offset	3
Derivative liabilities, Total Net Derivative Instruments	0
Interest rate contracts | Other current liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(3)
Interest rate contracts | Other current liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0
Interest rate contracts | Other current liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0
Interest rate contracts | Other long-term liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(2)
Derivative liabilities, Amounts Available for Offset	0	0
Derivative liabilities, Total Net Derivative Instruments	(2)	(4)
Interest rate contracts | Other long-term liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0
Interest rate contracts | Other long-term liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(2)
Interest rate contracts | Other long-term liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0
Commodity contracts
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(275)	(139)
Derivative liabilities, Total Net Derivative Instruments	(275)	(139)
Commodity contracts | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(246)	(54)
Commodity contracts | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(29)	(85)
Commodity contracts | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	0	0
Commodity contracts | Other current assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	206	302
Derivative assets, Amounts Available for Offset	(153)	(182)
Derivative assets, Total Net Derivative Instruments	53	120
Commodity contracts | Other current assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	206	302
Commodity contracts | Other current assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Commodity contracts | Other current assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Commodity contracts | Deferred amounts and other assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	57	61
Derivative assets, Amounts Available for Offset	(36)	(25)
Derivative assets, Total Net Derivative Instruments	21	36
Commodity contracts | Deferred amounts and other assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	57	61
Commodity contracts | Deferred amounts and other assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Commodity contracts | Deferred amounts and other assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets	0	0
Commodity contracts | Other current liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(362)	(332)
Derivative liabilities, Amounts Available for Offset	153	182
Derivative liabilities, Total Net Derivative Instruments	(209)	(150)
Commodity contracts | Other current liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(343)	(284)
Commodity contracts | Other current liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(19)	(48)
Commodity contracts | Other current liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0	0
Commodity contracts | Other long-term liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(176)	(170)
Derivative liabilities, Amounts Available for Offset	36	25
Derivative liabilities, Total Net Derivative Instruments	(140)	(145)
Commodity contracts | Other long-term liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(166)	(133)
Commodity contracts | Other long-term liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(10)	(37)
Commodity contracts | Other long-term liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0	0
Other contracts
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(4)	10
Derivative assets, Total Net Derivative Instruments		10
Derivative liabilities, Total Net Derivative Instruments	(4)
Other contracts | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(3)	9
Other contracts | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	(1)	1
Other contracts | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Total net financial asset/(liability)	0	0
Other contracts | Other current assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		7
Derivative assets, Amounts Available for Offset		0
Derivative assets, Total Net Derivative Instruments		7
Other contracts | Other current assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		7
Other contracts | Other current assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		0
Other contracts | Other current assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		0
Other contracts | Deferred amounts and other assets
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		3
Derivative assets, Amounts Available for Offset		0
Derivative assets, Total Net Derivative Instruments		3
Other contracts | Deferred amounts and other assets | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		2
Other contracts | Deferred amounts and other assets | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		1
Other contracts | Deferred amounts and other assets | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative assets		$ 0
Other contracts | Other current liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(2)
Derivative liabilities, Amounts Available for Offset	0
Derivative liabilities, Total Net Derivative Instruments	(2)
Other contracts | Other current liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(2)
Other contracts | Other current liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0
Other contracts | Other current liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	0
Other contracts | Other long-term liabilities
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(2)
Derivative liabilities, Amounts Available for Offset	0
Derivative liabilities, Total Net Derivative Instruments	(2)
Other contracts | Other long-term liabilities | Non-Qualifying Derivative Instruments
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(1)
Other contracts | Other long-term liabilities | Derivative Instruments Used as Cash Flow Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	(1)
Other contracts | Other long-term liabilities | Derivative Instruments Used as Fair Value Hedges | Designated as hedging instrument
TOTAL DERIVATIVE INSTRUMENTS
Derivative liabilities	$ 0

RISK MANAGEMENT AND FINANCIAL_6

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Notional Principal or Quantity Information (Details) - Sep. 30, 2023 € in Millions, ¥ in Millions, £ in Millions, $ in Millions, $ in Millions	USD ($) MWh MMBbls Bcf	GBP (£) MWh MMBbls Bcf	EUR (€) MWh MMBbls Bcf	JPY (¥) MWh MMBbls Bcf	CAD ($) MWh MMBbls Bcf
Foreign exchange contracts - forwards - purchase
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
Derivative Notional Amount Outstanding	$ 1,614			¥ 84,800
Foreign exchange contracts - forwards - purchase | United States dollar
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023	114
2024	1,000
2025	500
2026	0
2027	0
Thereafter	0
Foreign exchange contracts - forwards - purchase | Japanese yen
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023 | ¥				0
2024 | ¥				0
2025 | ¥				84,800
2026 | ¥				0
2027 | ¥				0
Thereafter | ¥				¥ 0
Foreign exchange contracts - forwards - sell
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
Derivative Notional Amount Outstanding	22,846	£ 127	€ 632
Foreign exchange contracts - forwards - sell | United States dollar
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023	1,593
2024	5,440
2025	4,955
2026	4,325
2027	3,647
Thereafter	$ 2,886
Foreign exchange contracts - forwards - sell | GBP
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023 | £		7
2024 | £		30
2025 | £		30
2026 | £		28
2027 | £		32
Thereafter | £		£ 0
Foreign exchange contracts - forwards - sell | Euro
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023 | €			27
2024 | €			91
2025 | €			86
2026 | €			85
2027 | €			81
Thereafter | €			€ 262
Interest rate contracts - short-term borrowings
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023					$ 2,656
2024					5,645
2025					1,364
2026					1,097
2027					75
Thereafter					39
Derivative Notional Amount Outstanding					10,876
Interest rate contracts - short-term debt receive
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023					229
2024					946
2025					946
2026					179
2027					0
Thereafter					0
Derivative Notional Amount Outstanding					2,300
Interest rate contracts - long-term debt pay fixed rate
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023					1,726
2024					400
2025					588
2026					0
2027					0
Thereafter					0
Derivative Notional Amount Outstanding					2,714
Interest Rate Contract, Costless Collar
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023					0
2024					0
2025					394
2026					11
2027					0
Thereafter					0
Derivative Notional Amount Outstanding					405
Equity contracts
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023					0
2024					33
2025					12
2026					0
2027					0
Thereafter					0
Derivative Notional Amount Outstanding					$ 45
Commodity contracts | Natural gas
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023 (bcf / mmbbls) | Bcf	6,000,000	6,000,000	6,000,000	6,000,000	6,000,000
2024 (bcf / mmbbls) | Bcf	45,000,000	45,000,000	45,000,000	45,000,000	45,000,000
2025 (bcf / mmbbls) | Bcf	27,000,000	27,000,000	27,000,000	27,000,000	27,000,000
2026 (bcf / mmbbls) | Bcf	9,000,000	9,000,000	9,000,000	9,000,000	9,000,000
2027 (bcf / mmbbls) | Bcf	7,000,000	7,000,000	7,000,000	7,000,000	7,000,000
Thereafter (bcf / mmbbls) | Bcf	0	0	0	0	0
Derivative Nonmonetary Notional Amount Outstanding | Bcf	94,000,000	94,000,000	94,000,000	94,000,000	94,000,000
Commodity contracts | Crude
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023 (bcf / mmbbls) | MMBbls	5,000,000	5,000,000	5,000,000	5,000,000	5,000,000
2024 (bcf / mmbbls) | MMBbls	(3,000,000)	(3,000,000)	(3,000,000)	(3,000,000)	(3,000,000)
2025 (bcf / mmbbls) | MMBbls	0	0	0	0	0
2026 (bcf / mmbbls) | MMBbls	0	0	0	0	0
2027 (bcf / mmbbls) | MMBbls	0	0	0	0	0
Thereafter (bcf / mmbbls) | MMBbls	0	0	0	0	0
Derivative Nonmonetary Notional Amount Outstanding | MMBbls	2,000,000	2,000,000	2,000,000	2,000,000	2,000,000
Net sell | Commodity contracts | Power
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
2023 (MWH) | MWh	61,000,000	61,000,000	61,000,000	61,000,000	61,000,000
2024 (MWH) | MWh	3,000,000	3,000,000	3,000,000	3,000,000	3,000,000
2025 (MW/H) | MWh	(42,000,000)	(42,000,000)	(42,000,000)	(42,000,000)	(42,000,000)
2026 (MWH) | MWh	(49,000,000)	(49,000,000)	(49,000,000)	(49,000,000)	(49,000,000)
2027 (MW/H) | MWh	(53,000,000)	(53,000,000)	(53,000,000)	(53,000,000)	(53,000,000)
Thereafter (MWH) | MWh	(50,000,000)	(50,000,000)	(50,000,000)	(50,000,000)	(50,000,000)
Total (MWH) | MWh	(33,000,000)	(33,000,000)	(33,000,000)	(33,000,000)	(33,000,000)

RISK MANAGEMENT AND FINANCIAL_7

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Fair Value Derivatives (Details) - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Foreign Currency Fair Value Hedge Derivative [Line Items]
Realized loss on derivative	$ (97)	$ (345)	$ (149)	$ (483)
Fair value hedges | Interest rate contracts
Foreign Currency Fair Value Hedge Derivative [Line Items]
Unrealized gain/(loss) on derivative	35	122	(107)	221
Unrealized gain/(loss) on hedged item	(35)	(122)	106	(211)
Realized loss on derivative	(11)	(5)	(34)	(101)
Realized gain on hedged item	$ 0	$ 0	$ 0	$ 85

RISK MANAGEMENT AND FINANCIAL_8

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Earnings and Comprehensive Income (Details) - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of unrealized gain/(loss) recognized in OCI	$ 334	$ 178	$ 487	$ 1,021
Amount of loss reclassified from AOCI to earnings	41	46	64	203
Estimated gain of AOCI related to cash flow hedges reclassified to earnings in the next 12 months			$ 20
Maximum term of hedging exposures to variability of cash flows			27 months
Total unrealized derivative fair value gain/(loss), net			$ 270	(1,691)
Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net	(865)	(1,276)	270	(1,691)
Foreign exchange contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of loss reclassified from AOCI to earnings	0	0	0	13
Foreign exchange contracts | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net	(650)	(1,379)	415	(1,752)
Foreign exchange contracts | Gas distribution sales revenues | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net			645	(375)
Foreign exchange contracts | Other income/(expense) | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net			(230)	(1,377)
Interest rate contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of loss reclassified from AOCI to earnings	40	45	63	187
Interest rate contracts | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net	17	17	72	1
Commodity contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of loss reclassified from AOCI to earnings	1	0	0	0
Commodity contracts | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net	(229)	89	(206)	59
Commodity contracts | Gas distribution sales revenues | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net			(85)	12
Commodity contracts | Commodity sales | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net			75	151
Commodity contracts | Commodity costs | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net			(136)	(116)
Commodity contracts | Operating and administrative expense | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net			(60)	12
Other contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of loss reclassified from AOCI to earnings	0	1	1	3
Other contracts | Non-Qualifying Derivative Instruments
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Total unrealized derivative fair value gain/(loss), net	(3)	(3)	(11)	1
Cash flow hedges | Foreign exchange contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of unrealized gain/(loss) recognized in OCI	0	1	0	3
Cash flow hedges | Interest rate contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of unrealized gain/(loss) recognized in OCI	313	230	423	1,087
Cash flow hedges | Commodity contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of unrealized gain/(loss) recognized in OCI	20	(16)	56	(27)
Cash flow hedges | Other contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of unrealized gain/(loss) recognized in OCI	(1)	(4)	(3)	(4)
Fair value hedges | Foreign exchange contracts
The Effect of Derivative Instruments on the Statements of Earnings and Comprehensive Income
Amount of unrealized gain/(loss) recognized in OCI	$ 2	$ (33)	$ 11	$ (38)

RISK MANAGEMENT AND FINANCIAL_9

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Liquidity and Credit Risk (Details) - CAD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
LIQUIDITY RISK AND CREDIT RISK
Rolling time period over which the Company forecasts cash requirements	12 months
Period of anticipated requirements for which the Company maintains sufficient liquidity through committed credit facilities	1 year
Derivative instruments
LIQUIDITY RISK AND CREDIT RISK
Maximum credit exposure with respect to derivative instruments	$ 1,030,000,000	$ 1,584,000,000
Cash collateral on asset exposure	0	0
Derivative instruments | Canadian financial institutions
LIQUIDITY RISK AND CREDIT RISK
Maximum credit exposure with respect to derivative instruments	495,000,000	644,000,000
Derivative instruments | US financial institutions
LIQUIDITY RISK AND CREDIT RISK
Maximum credit exposure with respect to derivative instruments	226,000,000	277,000,000
Derivative instruments | European financial institutions
LIQUIDITY RISK AND CREDIT RISK
Maximum credit exposure with respect to derivative instruments	123,000,000	334,000,000
Derivative instruments | Asian financial institutions
LIQUIDITY RISK AND CREDIT RISK
Maximum credit exposure with respect to derivative instruments	120,000,000	224,000,000
Derivative instruments | Other
LIQUIDITY RISK AND CREDIT RISK
Maximum credit exposure with respect to derivative instruments	$ 66,000,000	$ 105,000,000

RISK MANAGEMENT AND FINANCIA_10

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Fair Value of Derivatives (Details) - CAD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Fair Value of Derivatives
Total net financial asset/(liability)	$ (760)	$ (546)
Fair Value
Fair Value of Derivatives
Current derivative assets	693	1,015
Long-term derivative assets	346	627
Current derivative liabilities	(579)	(898)
Long-term derivative liabilities	(1,220)	(1,290)
Total net financial asset/(liability)	(760)	(546)
Foreign exchange contracts
Fair Value of Derivatives
Total net financial asset/(liability)	(1,009)	(1,327)
Foreign exchange contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	103	46
Long-term derivative assets	140	309
Current derivative liabilities	(212)	(566)
Long-term derivative liabilities	(1,040)	(1,116)
Total net financial asset/(liability)	(1,009)	(1,327)
Interest rate contracts
Fair Value of Derivatives
Total net financial asset/(liability)	528	910
Interest rate contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	384	660
Long-term derivative assets	149	254
Current derivative liabilities	(3)
Long-term derivative liabilities	(2)	(4)
Total net financial asset/(liability)	528	910
Commodity contracts
Fair Value of Derivatives
Total net financial asset/(liability)	(275)	(139)
Commodity contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	206	302
Long-term derivative assets	57	61
Current derivative liabilities	(362)	(332)
Long-term derivative liabilities	(176)	(170)
Total net financial asset/(liability)	(275)	(139)
Other contracts
Fair Value of Derivatives
Total net financial asset/(liability)	(4)	10
Other contracts | Fair Value
Fair Value of Derivatives
Current derivative assets		7
Long-term derivative assets		3
Current derivative liabilities	(2)
Long-term derivative liabilities	(2)
Total net financial asset/(liability)	(4)	10
Level 1 | Fair Value
Fair Value of Derivatives
Current derivative assets	58	65
Long-term derivative assets	0	0
Current derivative liabilities	(93)	(60)
Long-term derivative liabilities	0	0
Total net financial asset/(liability)	(35)	5
Level 1 | Foreign exchange contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	0	0
Long-term derivative assets	0	0
Current derivative liabilities	0	0
Long-term derivative liabilities	0	0
Total net financial asset/(liability)	0	0
Level 1 | Interest rate contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	0	0
Long-term derivative assets	0	0
Current derivative liabilities	0
Long-term derivative liabilities	0	0
Total net financial asset/(liability)	0	0
Level 1 | Commodity contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	58	65
Long-term derivative assets	0	0
Current derivative liabilities	(93)	(60)
Long-term derivative liabilities	0	0
Total net financial asset/(liability)	(35)	5
Level 1 | Other contracts | Fair Value
Fair Value of Derivatives
Current derivative assets		0
Long-term derivative assets		0
Current derivative liabilities	0
Long-term derivative liabilities	0
Total net financial asset/(liability)	0	0
Level 2 | Fair Value
Fair Value of Derivatives
Current derivative assets	523	803
Long-term derivative assets	305	583
Current derivative liabilities	(267)	(643)
Long-term derivative liabilities	(1,064)	(1,158)
Total net financial asset/(liability)	(503)	(415)
Level 2 | Foreign exchange contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	103	46
Long-term derivative assets	140	309
Current derivative liabilities	(212)	(566)
Long-term derivative liabilities	(1,040)	(1,116)
Total net financial asset/(liability)	(1,009)	(1,327)
Level 2 | Interest rate contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	384	660
Long-term derivative assets	149	254
Current derivative liabilities	(3)
Long-term derivative liabilities	(2)	(4)
Total net financial asset/(liability)	528	910
Level 2 | Commodity contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	36	90
Long-term derivative assets	16	17
Current derivative liabilities	(50)	(77)
Long-term derivative liabilities	(20)	(38)
Total net financial asset/(liability)	(18)	(8)
Level 2 | Other contracts | Fair Value
Fair Value of Derivatives
Current derivative assets		7
Long-term derivative assets		3
Current derivative liabilities	(2)
Long-term derivative liabilities	(2)
Total net financial asset/(liability)	(4)	10
Level 3
Fair Value of Derivatives
Total net financial asset/(liability)	(222)
Level 3 | Fair Value
Fair Value of Derivatives
Current derivative assets	112	147
Long-term derivative assets	41	44
Current derivative liabilities	(219)	(195)
Long-term derivative liabilities	(156)	(132)
Total net financial asset/(liability)	(222)	(136)
Level 3 | Foreign exchange contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	0	0
Long-term derivative assets	0	0
Current derivative liabilities	0	0
Long-term derivative liabilities	0	0
Total net financial asset/(liability)	0	0
Level 3 | Interest rate contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	0	0
Long-term derivative assets	0	0
Current derivative liabilities	0
Long-term derivative liabilities	0	0
Total net financial asset/(liability)	0	0
Level 3 | Commodity contracts | Fair Value
Fair Value of Derivatives
Current derivative assets	112	147
Long-term derivative assets	41	44
Current derivative liabilities	(219)	(195)
Long-term derivative liabilities	(156)	(132)
Total net financial asset/(liability)	(222)	(136)
Level 3 | Other contracts | Fair Value
Fair Value of Derivatives
Current derivative assets		0
Long-term derivative assets		0
Current derivative liabilities	0
Long-term derivative liabilities	0
Total net financial asset/(liability)	$ 0	$ 0

RISK MANAGEMENT AND FINANCIA_11

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Level 3 Inputs (Details) $ in Millions	Sep. 30, 2023 CAD ($) $ / MillionsofBTU-MMBTU $ / MWh $ / bbl	Dec. 31, 2022 CAD ($)
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	$ (760)	$ (546)
Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	(760)	(546)
Level 3
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	(222)
Level 3 | Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	(222)	$ (136)
Market approach valuation technique | Level 3 | Commodity contracts - financial | Natural gas | Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	$ (20)
Market approach valuation technique | Level 3 | Commodity contracts - financial | Natural gas | Minimum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MillionsofBTU-MMBTU	1.69
Market approach valuation technique | Level 3 | Commodity contracts - financial | Natural gas | Maximum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MillionsofBTU-MMBTU	10.93
Market approach valuation technique | Level 3 | Commodity contracts - financial | Natural gas | Weighted Average
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MillionsofBTU-MMBTU	4.67
Market approach valuation technique | Level 3 | Commodity contracts - financial | Crude | Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	$ (32)
Market approach valuation technique | Level 3 | Commodity contracts - financial | Crude | Minimum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / bbl	83.38
Market approach valuation technique | Level 3 | Commodity contracts - financial | Crude | Maximum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / bbl	120.51
Market approach valuation technique | Level 3 | Commodity contracts - financial | Crude | Weighted Average
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / bbl	98.08
Market approach valuation technique | Level 3 | Commodity contracts - financial | Power | Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	$ (77)
Market approach valuation technique | Level 3 | Commodity contracts - financial | Power | Minimum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MWh	30.75
Market approach valuation technique | Level 3 | Commodity contracts - financial | Power | Maximum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MWh	160.92
Market approach valuation technique | Level 3 | Commodity contracts - financial | Power | Weighted Average
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MWh	65.98
Market approach valuation technique | Level 3 | Commodity contracts - physical | Natural gas | Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	$ (13)
Market approach valuation technique | Level 3 | Commodity contracts - physical | Natural gas | Minimum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MillionsofBTU-MMBTU	1.58
Market approach valuation technique | Level 3 | Commodity contracts - physical | Natural gas | Maximum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MillionsofBTU-MMBTU	23.92
Market approach valuation technique | Level 3 | Commodity contracts - physical | Natural gas | Weighted Average
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MillionsofBTU-MMBTU	5.04
Market approach valuation technique | Level 3 | Commodity contracts - physical | Crude | Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	$ (19)
Market approach valuation technique | Level 3 | Commodity contracts - physical | Crude | Minimum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / bbl	84.35
Market approach valuation technique | Level 3 | Commodity contracts - physical | Crude | Maximum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / bbl	128.65
Market approach valuation technique | Level 3 | Commodity contracts - physical | Crude | Weighted Average
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / bbl	107.59
Market approach valuation technique | Level 3 | Commodity contracts - physical | Power | Fair Value
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Fair Value	$ (61)
Market approach valuation technique | Level 3 | Commodity contracts - physical | Power | Minimum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MWh	24.47
Market approach valuation technique | Level 3 | Commodity contracts - physical | Power | Maximum
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MWh	164.58
Market approach valuation technique | Level 3 | Commodity contracts - physical | Power | Weighted Average
Significant unobservable inputs used in the fair value measurement of Level 3 derivative instruments
Forward price ($ / mmbtu, barrel, gallon, MW/H) | $ / MWh	61.70

RISK MANAGEMENT AND FINANCIA_12

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Changes in Level 3 (Details) - CAD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Changes in net fair value of derivative assets and liabilities classified as Level 3
Level 3 net derivative liability at beginning of period	$ (136)	$ (108)
Total gain/(loss)
Included in earnings	(205)	41
Included in OCI	0	(28)
Settlements	119	(2)
Level 3 net derivative liability at end of period	$ (222)	$ (97)

RISK MANAGEMENT AND FINANCIA_13

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS - Other Financial Instruments (Details) - CAD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Fair Value of Other Financial Instruments
Unrealized gains (losses) on the change in fair value of foreign exchange foreign contracts			$ 0	$ 0
Realized gain (loss) recognized in OCI associated with settlement of foreign exchange forward contracts			0	0
FMVA investments	$ 209,000,000		209,000,000		$ 102,000,000
Restricted long-term investments	635,000,000		635,000,000		593,000,000
Long-term debt, carrying value	76,300,000,000		76,300,000,000		79,300,000,000
Long-term debt	68,900,000,000		68,900,000,000		73,500,000,000
Debt Securities
Fair Value of Other Financial Instruments
Debt securities, available-for-sale, amortized cost	346,000,000		346,000,000		295,000,000
Equity Funds And Debt Securities
Fair Value of Other Financial Instruments
Unrealized gain (loss) on lnvestments	(8,000,000)	$ (13,000,000)	14,000,000	(40,000,000)
Net investment hedges
Fair Value of Other Financial Instruments
Unrealized foreign exchange gain (loss) on translation of United States dollar denominated debt			86,000,000	(1,191,000,000)
Realized loss associated with the settlement of foreign exchange forward contracts			44,000,000	0
Level 1
Fair Value of Other Financial Instruments
Restricted long-term investments	252,000,000		252,000,000		236,000,000
Level 1 | Debt Securities
Fair Value of Other Financial Instruments
Fair value of investments	273,000,000		273,000,000		335,000,000
Level 2
Fair Value of Other Financial Instruments
Restricted long-term investments	383,000,000		383,000,000		357,000,000
Restricted long-term investments, cost basis	474,000,000		474,000,000		437,000,000
Level 2 | Debt Securities
Fair Value of Other Financial Instruments
Fair value of investments	353,000,000		353,000,000		298,000,000
Fair Value
Fair Value of Other Financial Instruments
Restricted long-term investments	635,000,000		635,000,000		593,000,000
Unrealized holding gains (losses)	(44,000,000)	$ 11,000,000	(7,000,000)	$ (120,000,000)
Fair value note receivable	660,000,000		660,000,000		752,000,000
Carrying value
Fair Value of Other Financial Instruments
Non-current notes receivable	$ 660,000,000		$ 660,000,000		$ 752,000,000

INCOME TAXES (Details)

INCOME TAXES (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Effective income tax rate (as a percent)	17%	18.70%	20.50%	20.50%

OTHER INCOME_(EXPENSE) (Details

OTHER INCOME/(EXPENSE) (Details) - CAD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Other Income and Expenses [Abstract]
Gain on dispositions	$ 4	$ 1	$ 15	$ 0
Realized foreign currency gain	31	106	177	110
Unrealized foreign currency loss	(652)	(1,129)	(348)	(1,345)
Net defined pension and OPEB credit	34	59	101	176
Other	118	80	267	135
Total	$ (465)	$ (883)	$ 212	$ (924)

SUBSEQUENT EVENT (Details)

SUBSEQUENT EVENT (Details) - Subsequent event € in Millions, $ in Millions	Nov. 03, 2023 CAD ($)	Nov. 03, 2023 EUR (€)	Nov. 01, 2023 CAD ($)
Aitken Creek Gas Storage Facility And Aitken Creek North Gas Storage Facility
Subsequent Event [Line Items]
Cash			$ 400
Aitken Creek Gas Storage
Subsequent Event [Line Items]
Ownership interest (in percent)			93.80%
Aitken Creek North Gas
Subsequent Event [Line Items]
Ownership interest (in percent)			100%
Hohe See Offshore And Albatros Offshore Wind Farm
Subsequent Event [Line Items]
Ownership interest (in percent)	49.90%	49.90%
Ownership interest acquired additionally (in percent)	24.45%	24.45%
Cash	$ 391	€ 267
Assumed debt	$ 524	€ 358
Enbridge Renewable Infrastructure Investments S a r l (ERII)
Subsequent Event [Line Items]
Ownership interest acquired additionally (in percent)	49%	49%