Brookfield Renewable Partners (BEP) 20-F 28 Feb 19 2018 FY Annual report (foreign) Financial data

Document and Entity Information

Document and Entity Information	12 Months Ended
	Dec. 31, 2018USD ($)shares
Document And Entity Infromation [Line Items]
Entity Registrant Name	BROOKFIELD RENEWABLE PARTNERS L.P.
Entity Central Index Key	1,533,232
Trading Symbol	BEP
Document type	20-F
Document period end date	Dec. 31, 2018
Amendment flag	false
Current Fiscal Year End Date	--12-31
Entity Well Known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	FY
Limited Partnership units
Document And Entity Infromation [Line Items]
Entity Public Float | $	$ 4,513,447,189
Entity LP Units Outstanding | shares	178,821,204
General partnership units
Document And Entity Infromation [Line Items]
Entity Public Float | $	$ 66,924,011
Entity LP Units Outstanding | shares	2,651,506
Redeemable/Exchangeable partnership units
Document And Entity Infromation [Line Items]
Entity Public Float | $	$ 3,272,583,645
Entity LP Units Outstanding | shares	129,658,623

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Consolidated Statment of Income (Loss) [line items]
Revenues	$ 2,982	$ 2,625	$ 2,452
Other income	50	47	64
Direct operating costs	(1,036)	(978)	(1,038)
Management service costs	(80)	(82)	(62)
Interest expense borrowings	(705)	(632)	(606)
Share of net income	(68)	(2)	0
Unrealized loss (gain) through income	34	46	(4)
Depreciation	(819)	(782)	(781)
Other	(82)	(15)	(46)
Income tax (expense) recovery
Current	(30)	(39)	(44)
Deferred	89	(49)	97
Total Income Tax recovery (expense)	59	(88)	53
Net (loss) income	403	51	40
Net (loss) income attributable to:
Non-controlling interests	274	288	65
Preferred limited partners' equity	38	28	15
Limited partners' equity	$ 24	$ (32)	$ (36)
Basic and Diluted earnings per LP unit	$ 0.13	$ (0.18)	$ (0.23)
Non-controlling interests [member]
Consolidated Statment of Income (Loss) [line items]
Revenues	$ 2,982	$ 2,625	$ 2,452
Income tax (expense) recovery
Net (loss) income	403	51	40
Participating Non-controlling Interests Operating Subsidiaries
Income tax (expense) recovery
Net (loss) income	297	53	65
Net (loss) income attributable to:
Non-controlling interests	297	53	65
General partnership interest in a holding subsidiary held by Brookfield
Income tax (expense) recovery
Net (loss) income	1	(1)	0
Net (loss) income attributable to:
Non-controlling interests	1	(1)	0
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Income tax (expense) recovery
Net (loss) income	17	(23)	(29)
Net (loss) income attributable to:
Non-controlling interests	17	(23)	(29)
Preferred equity
Income tax (expense) recovery
Net (loss) income	26	26	25
Net (loss) income attributable to:
Non-controlling interests	$ 26	$ 26	$ 25

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	$ 403	$ 51	$ 40
Other comprehensive income that will not be reclassified to net income
Revaluations of property, plant and equipment	4,558	872	417
Revaluations of property, plant and equipment related to equity-accounted investments	426	54	7
Actuarial (loss) gain on defined benefit plans	9	(2)	(2)
Deferred income taxes on above items	(975)	338	(34)
Total items that will not be reclassified to net income	4,018	1,262	388
Other comprehensive income (loss) that may be reclassified to net income
Foreign currency translation	(825)	190	986
(Losses) gains arising during the year on financial instruments designated as cash-flow hedges ##FI	(5)	4	8
Unrealized (loss) gain on foreign currency swaps - net investment hedge	93	(94)	(66)
Unrealized (loss) gain on investments in equity and debt securities	(16)	(22)	61
Reclassification adjustments for amounts recognized in net income	18	(1)	(41)
Deferred income taxes on above items	(19)	11	(7)
Total items that may be reclassified subsequently to net income	(754)	88	941
Other comprehensive income	3,264	1,350	1,329
Comprehensive income	3,667	1,401	1,369
Comprehensive income attributable to:
Preferred limited partners' equity	38	28	15
Limited partners' equity	950	494	332
Comprehensive income	3,667	1,401	1,369
Non-controlling interests [member]
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	403	51	40
Other comprehensive income (loss) that may be reclassified to net income
Comprehensive income	3,667	1,401	1,369
Comprehensive income attributable to:
Comprehensive income	3,667	1,401	1,369
Participating Non-controlling Interests Operating Subsidiaries
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	297	53	65
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	1,707	383	635
Comprehensive income attributable to:
Non-controlling interests	2,004	436	700
General partnership interest in a holding subsidiary held by Brookfield
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	1	(1)	0
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	13	9	6
Comprehensive income attributable to:
Non-controlling interests	14	8	6
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	17	(23)	(29)
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	666	393	304
Comprehensive income attributable to:
Non-controlling interests	683	370	275
Preferred equity
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	26	26	25
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	(48)	39	16
Comprehensive income attributable to:
Non-controlling interests	$ (22)	$ 65	$ 41

CONSOLIDATED STATEMENTS OF FINA

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents	$ 173	$ 799
Restricted cash	136	181
Trade receivables and other current assets	607	554
Financial instrument assets	60	72
Due from related parties	65	60
Assets held for sale	920	0
Total Current Assets	1,961	1,666
Financial instrument assets	124	113
Equity-accounted investments	1,569	721
Property, plant and equipment, at fair value	29,025	27,096
Goodwill	828	901
Deferred income tax assets	91	177
Other long-term assets	505	230
Total Assets	34,103	30,904
Current liabilities
Accounts payable and accrued liabilities	533	542
Financial instrument liabilities	27	184
Due to related parties	101	112
Corporate Borrowings	6	159
Non-recourse borrowings	489	1,517
Liabilities directly associated with assets held for sale	489	0
Total Current Liabilities	1,689	2,514
Financial instrument liabilities	111	86
Long-term debt and credit facilities	2,328	2,393
Non Recourse Borrowings	7,895	7,697
Deferred income tax liabilities	4,140	3,588
Other long-term liabilities	734	344
Total Liabilities	16,897	16,622
Equity
Non-controlling interests	8,129	6,298
Preferred limited partners' equity	707	511
Limited partners' equity	4,484	3,956
Total Equity	17,206	14,282
Total Equity And Liabilities	34,103	30,904
Non-controlling interests
Current assets
Property, plant and equipment, at fair value	29,025	27,096
Total Assets	34,103	30,904
Current liabilities
Total Liabilities	16,897	16,622
Equity
Non-controlling interests	12,015	9,815
Participating Non-controlling Interests Operating Subsidiaries
Equity
Non-controlling interests	8,129	6,298
Total Equity	8,129	6,298
General partnership interest in a holding subsidiary held by Brookfield
Equity
Non-controlling interests	66	58
Total Equity	66	58
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Equity
Non-controlling interests	3,252	2,843
Total Equity	3,252	2,843
Preferred equity
Equity
Non-controlling interests	568	616
Total Equity	$ 568	$ 616

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Limited Partners' Equity	Limited Partners' Equity	Foreign Currency Translation	Revaluation Surplus	Actuarial losses on defined benefit plans	Cash flow hedges	Investments in Equtiy Securities	Preferred limited partners' equity	Non-controlling interests	Preferred equity	Participating Non-controlling Interests Operating Subsidiaries	General partnership interest in a holding subsidiary held by Brookfield	Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Balance, as at at Dec. 31, 2015	$ 8,763	$ 2,827	$ (485)	$ (670)	$ 4,019	$ (7)	$ (30)	$ 0	$ 128		$ 610	$ 2,587	$ 52	$ 2,559
Net (loss) income	40	(36)	(36)	0	0	0	0	0	15	$ 40	25	65	0	(29)
Other comprehensive income	1,329	368	0	241	105	(1)	(1)	24	0		16	635	6	304
Preferred LP Units issued	(147)
Preferred LP Units and LP Units issued	804	657	657	0	0	0	0	0	147
Adjustment	0	(85)	(85)								0	0	2	83
Exchange of preferred shares	0								49		(49)
Capital contributions from participating non-controlling interests - in operating subsidiaries	2,621										0	2,621	0	0
Acquisition	1,417										0	1,417	0	0
Distributions or dividends declared	(696)	(281)	(281)	0	0	0	0	0	(15)		(25)	(119)	(24)	(232)
Distribution reinvestment plan	9	9	9	0	0	0	0	0	0		0	0	0	0
MTO adjustments	(1,616)	1	(24)	25	0	0	0	0	0		0	(1,617)	0	0
Other	1	(12)	(12)	0	0	0	0	0	0		(1)	0	19	(5)
Change in year	3,909	621	228	266	105	(1)	(1)	24	196		(34)	3,002	3	121
Balance, as at at Dec. 31, 2016	12,672	3,448	(257)	(404)	4,124	(8)	(31)	24	324		576	5,589	55	2,680
Net (loss) income	51	(32)	(32)	0	0	0	0	0	28	51	26	53	(1)	(23)
Other comprehensive income	1,350	526	0	26	508	(1)	2	(9)	0		39	383	9	393
Preferred LP Units issued	(187)
Preferred LP Units and LP Units issued	598	411	411	0	0	0	0	0	187		0	0	0	0
Adjustment	0	(63)	(63)	0	0	0	0	0	0		0	0	1	62
Capital contributions from participating non-controlling interests - in operating subsidiaries	294	0	0	0	0	0	0	0	0		0	294	0	0
Acquisition	525	0	0	0	0	0	0	0	0		0	525	0	0
Distributions or dividends declared	(1,199)	(328)	(328)	0	0	0	0	0	(28)		(26)	(539)	(35)	(243)
Distribution reinvestment plan	10	10	10	0	0	0	0	0	0		0	0	0	0
MTO adjustments	0	0	0	0	0	0	0	0	0		0	0	0	0
Other	(19)	(16)	0	0	(16)	0	0	0	0		1	(7)	29	(26)
Change in year	1,610	508	(2)	26	492	(1)	2	(9)	187		40	709	3	163
Balance, as at at Dec. 31, 2017	14,282	3,956	(259)	(378)	4,616	(9)	(29)	15	511		616	6,298	58	2,843
Net (loss) income	403	24	24	0	0	0	0	0	38	$ 403	26	297	1	17
Other comprehensive income	3,264	926	0	(205)	1,131	3	5	(8)	0		(48)	1,707	13	666
Preferred LP Units issued	(196)	0	0	0	0	0	0	0	196		0	0	0	0
LP Units and preferred shares purchased for cancellation	(51)	(51)	(51)	0	0	0	0	0	0		0	0	0	0
Capital contributions from participating non-controlling interests - in operating subsidiaries	307	0	0	0	0	0	0	0	0		0	307	0	0
Acquisition	21	0	0	0	0	0	0	0	0		0	21	0	0
Distributions or dividends declared	(1,272)	(355)	(355)	0	0	0	0	0	(38)		(26)	(553)	(45)	(255)
Distribution reinvestment plan	8	8	8	0	0	0	0	0	0		0	0	0	0
Other	48	(24)	(315)	(69)	373	0	(10)	(3)	0		0	52	39	(19)
Change in year	2,924	528	(689)	(274)	1,504	3	(5)	(11)	196		(48)	1,831	8	409
Balance, as at at Dec. 31, 2018	$ 17,206	$ 4,484	$ (948)	$ (652)	$ 6,120	$ (6)	$ (34)	$ 4	$ 707		$ 568	$ 8,129	$ 66	$ 3,252

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating activities
Net (loss) income	$ 403,000,000	$ 51,000,000	$ 40,000,000
Adjustments for the following non-cash items:
Depreciation	819,000,000	782,000,000	781,000,000
Foreign exchange and unrealized financial instruments (loss) gain	(34,000,000)	(46,000,000)	4,000,000
Share of earnings from equity-accounted investments	68,000,000	2,000,000	0
Deferred income tax (recovery) expense	89,000,000	(49,000,000)	97,000,000
Other non-cash items	53,000,000	(6,000,000)	27,000,000
Dividends received from equity-accounted investments	42,000,000	31,000,000	6,000,000
Changes in due to or from related parties	3,000,000	5,000,000	11,000,000
Net change in working capital balances	(68,000,000)	(25,000,000)	(137,000,000)
Cash Flows From (Used In) Operating Activities	1,103,000,000	928,000,000	632,000,000
Financing activities
Long-term debt - borrowings	3,261,000,000	1,874,000,000	3,477,000,000
Long-term debt - repayments	(3,527,000,000)	(1,607,000,000)	(1,975,000,000)
Capital contributions from participating non-controlling interests - in operating subsidiaries	(307,000,000)	(294,000,000)	(2,621,000,000)
Acquisition of Isagen from non-controlling interests	0	(5,000,000)	(1,540,000,000)
Issuance of preferred limited partnership units	196,000,000	187,000,000	147,000,000
Issuance of LP Units	0	(411,000,000)	(657,000,000)
Repurchase of LP Units	(51,000,000)	0	0
Distributions paid:
To participating non-controlling interests - in operating subsidiaries	(553,000,000)	(539,000,000)	(119,000,000)
To preferred shareholders	(26,000,000)	(25,000,000)	(25,000,000)
To preferred limited partners' unitholders	(37,000,000)	(26,000,000)	(12,000,000)
To unitholders of Brookfield Renewable or BRELP	(643,000,000)	(591,000,000)	(522,000,000)
Borrowings from related party	200,000,000	0	0
Repayments to related party	(200,000,000)	0	0
Cash Flows From Used In Financing Activities	(1,080,000,000)	(27,000,000)	2,709,000,000
Investing activities
Acquisitions net of cash and cash equivalents in acquired entity	(39,000,000)	377,000,000	(2,769,000,000)
Investment in equity accounted investments	(420,000,000)	(439,000,000)	0
Investment in property, plant and equipment	(235,000,000)	(355,000,000)	(369,000,000)
Proceeds from disposal of assets	23,000,000	150,000,000	0
Disposal of (investment in) securities	27,000,000	(77,000,000)	(60,000,000)
Restricted cash and other	20,000,000	16,000,000	7,000,000
Cash Flows From Used In Investing Activities	(624,000,000)	(328,000,000)	(3,191,000,000)
Foreign exchange gain on cash	(17,000,000)	3,000,000	10,000,000
Net Change In Cash Classified Within Assets Held For Sale	(8,000,000)	0	0
Cash and cash equivalents
Increase (decrease)	(618,000,000)	576,000,000	160,000,000
Balance, beginning of period	799,000,000	223,000,000	63,000,000
Balance, end of period	173,000,000	799,000,000	223,000,000
Supplemental cash flow information:
Interest paid	665,000,000	611,000,000	588,000,000
Interest received	22,000,000	27,000,000	40,000,000
Income taxes paid	68,000,000	48,000,000	55,000,000
Non-controlling interests [member]
Operating activities
Net (loss) income	403,000,000	51,000,000	40,000,000
Participating Non-controlling Interests Operating Subsidiaries
Operating activities
Net (loss) income	297,000,000	53,000,000	65,000,000
Financing activities
Capital contributions from participating non-controlling interests - in operating subsidiaries	(307,000,000)	(294,000,000)	(2,621,000,000)
Issuance of preferred limited partnership units	0
Preferred equity
Operating activities
Net (loss) income	26,000,000	26,000,000	25,000,000
Financing activities
Capital contributions from participating non-controlling interests - in operating subsidiaries	0	$ 0	$ 0
Issuance of preferred limited partnership units	$ 0

BASIS OF PREPARATION AND SIGNIF

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES	1 . BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES ( a) Statement of compliance The consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”). The accounting policies used in the consolidated financial statements are based on the IFRS applicable as at December 31, 2018, which encompass individual IFRS, International Accounting Standards (“IAS”), and interpret ations made by the International Financial Reporting Interpretations Committee (“IFRIC”) and the Standard Interpretations Committee (“SIC”). The policies set out below are consistently applied to all periods presented, unless otherwise noted. These conso lidated financial statements have been authorized for issuance by the Board of Directors of Brookfield Renewable’s general partner, BRPL , on February 28, 2019 . Certain comparative figures have been reclassified to conform to the current year’s presentation. References to $, C$, € , £ ,R $, COP , ZAR, THB and MYR are to United States (“U.S.”) dollars, Canadian dollars, Euros, British p ound sterling , Brazilian reais , Colombian pesos, South African rand, Thai baht and Malaysian ringgit, respectively. All figures are presented in millions of U.S. dollars unless otherwise noted. (b) Basis of preparation The consolidated financial statements have been prepared on the basis of historical cost, except for the revaluation of property, plant and equipment and certain assets and liabilities which have been measured at fair value. Cost is recorded based on the fair value of the consideration given in exchange for assets. (i) Consolidation These consolidated financial statements include the accounts of Brookfield Renewable and its subsidiaries, which are the entities over which Brook field Renewable has control. An investor controls an investee when it is exposed, or has rights, to variable returns from its involvement with the investee and has the ability to affect those returns through its power over the investee. Non-controlling int erests in the equity of Brookfield Renewable’s subsidiaries are shown separately in equity in the consolidated statements of financial position. Brookfield Renewable has entered into a voting agreement with Brookfield, which provides Brookfield Renewable w ith control of the general partner of Brookfield Renewable Energy L.P. (“BRELP”), a holding subsidiary. Accordingly, Brookfield Renewable consolidates the accounts of BRELP and its subsidiaries. In addition, BRELP issued redeemable/exchangeable limited par tnership units to Brookfield (“Redeemable/Exchangeable Partnership Units”), pursuant to which the holder may at its request require BRELP to redeem the Redeemable/Exchangeable Partnership Units for cash consideration. This right is subject to Brookfield Re newable’s right of first refusal which entitles it, at its sole discretion, to elect to acquire all of the Redeemable/Exchangeable Partnership Units so presented to BRELP that are tendered for redemption in exchange for LP Units on a one for one basis . As Brookfield Renewable, a t its sole discretion, has the right to settle the obligation with LP Units, the Redeemable/Exchangeable Partnership Units are classified as equity of Brookfield Renewable (“Participating non-controlling interests – in a holding subsidiary – Redeemable/Exc hangeable Units held by Brookfield”). Brookfield Renewable has entered into voting agreements with Brookfield, whereby Brookfield Renewable gained control of the entities that own certain renewable power generating operations in the United States, Brazil, Europe and other countries (including India and China). Brookfield Renewable has also entered into a voting agreement with our consortium partners in respect of our Colombian operations. These voting agreements provide Brookfield Renewable the authority to direct the election of the Boards of Directors of the relevant entities, among other things, and therefore provide Brookfield Renewable with control. Accordingly, Brookfield Renewable consolidates the accounts of these entities. Refer to Note 27 - Relat ed party transactions for further information. For entities previously controlled by Brookfield Asset Management, the voting agreements entered into do not represent business combinations in accordance with IFRS 3, Business Combinations (“ IFRS 3” ) , as all combining businesses are ultimately controlled by Brookfield Asset Management both before and after the transactions were completed. Brookfield Renewable accounts for these transactions involving entities under common control in a manner similar to a pooli ng of interest, which requires the presentation of pre-voting agreement financial information as if the transactions had always been in place. Refer to Note 1(r)(ii) - Critical judgments in applying accounting policies - Common control transactions for Bro okfield Renewable’s policy on accounting for transactions under common control. (ii) Equity-accounted investments Equity-accounted investments are entities over which Brookfield Renewable has significant influence or joint arrangements representing jo int ventures. Significant influence is the ability to participate in the financial and operating policy decisions of the investee, but without controlling or jointly controlling those investees. Such investments are accounted for using the equity method. A joint venture is a type of joint arrangement whereby the parties that have joint control of the arrangement have rights to the net assets of the joint venture. Joint control is the contractually agreed sharing of control of an arrangement, which exists o nly when decisions about the relevant activities require unanimous consent of the parties sharing control. Brookfield Renewable accounts for its interests in joint ventures using the equity method. Under the equity method, the carrying value of an interes t in an investee is initially recognized at cost and adjusted for Brookfield Renewable’s share of net income, other comprehensive income (“OCI”), distributions by the equity-accounted investment and other adjustments to Brookfield Renewable’s proportionate interest in the investee. (c) Recently adopted accounting standards (i) IFRS 15, Revenue from contracts with customers (“IFRS 15”) On January 1, 2018 Brookfield Renewable adopted IFRS 15 using the modified retrospective method applied to those contracts which were not completed as of January 1, 2018. IFRS 15 supersedes IAS 11 Construction Contracts, IAS 18 Revenue and related interpre tations and it applies, with limited exceptions, to all revenue arising from contracts with its customers. IFRS 15 requires that revenue be recognized at an amount that reflects the consideration to which an entity expects to be entitled in exchange for tr ansferring goods or services to a customer using a five-step model , which requires the identification of a contract with a customer, the identification of performance obligations within the contract, determination of the transaction price, the allocation o f the transaction price to the performance obligations and the recognition of revenue when performance obligations have been satisfied. IFRS 15 requires entities to exercise judgement, taking into consideration all the relevant facts and circumstances whe n applying each step of the model to contracts with their customers. The standard also specifies the accounting for the incremental costs of obtaining a contract and the costs directly related to fulfilling a contract. The pattern and timing of revenue rec ognition under the new standard is consistent with prior practice. There were no adjustments recognized on the adoption of IFRS 15. (ii) IFRS 9, Financial instruments (“IFRS 9”) Brookfield Renewable adopted IFRS 9, as issued by the IASB in 2014, which pr ovides more reliable and relevant information for users to assess the amounts, timing and uncertainty of future cash flows. The new accounting policy was applied prospectively, with an initial application date of January 1, 2018. Brookfield Renewable has n ot restated the comparative information, which continues to be reported under IAS 39, Financial Instruments Recognition and Measurement (“IAS 39”). The adoption of IFRS 9 did not result in any material transition adjustments being recognized as at January 1, 2018 IFRS 9 replaces certain provisions of IAS 39 that relate to the recognition, classification and measurement of financial assets and financial liabilities; derecognition of financial instruments; impairment of financial assets; and hedge accounting. IFRS 9 also significantly amends other standards dealing with financial instruments such as IFRS 7, Financial Instruments: Disclosures . (d) C hanges to and impact of financial instrument accounting policies Classification and measurement Under IFRS 9, financial assets are subsequently measured at fair value through profit or loss, amortiz ed cost, or fair value through OCI. The classification is based on two criteria: Brookfield Renewable’s business objectives for managing the assets; and whether the instruments’ contractual cash flows represent ‘solely payments of principal and interest’ on the principal amount outstanding. The assessment of Brookfield Renewable’s business objectives was made as of January 1, 2018, the date of initial application. The assessment of whether contractual cash flows on debt instruments are solely comprised of pri ncipal and interest was made based on the facts and circumstances as at the initial recognition of the assets. As at January 1, 2018, the date of initial application, Brookfield Renewable ’s financial instruments and new classification categories under IFRS 9 were as follows: Classification category IAS 39 IFRS 9 Carrying amount IAS 39 and IFRS 9 ($ Millions) Financial assets Cash and cash equivalents FVPL Amortized cost 799 Restricted cash (1) FVPL Amortized cost 284 Trade receivables and other current assets Loans and receivables Amortized cost 554 Financial instrument assets - investments in equity securities (1)(2) Available-for-sale FVOCI 159 Financial instrument assets - derivative financial instruments (1)(3) FVPL FVPL 20 Financial instrument assets - derivative financial instruments designated as hedges (1)(3) Financial instruments designated as hedges Financial instruments designated as hedges 6 Due from related parties Loans and receivables Amortized cost 60 Financial liabilities Accounts payable and accrued liabilities Other liabilities Amortized cost 542 Financial instrument liabilities - derivative financial instruments (1)(3) FVPL FVPL 145 Financial instrument liabilities - derivative financial instruments designated as hedges (1)(3) Financial instruments designated as hedges Financial instruments designated as hedges 125 Due to related parties Other liabilities Amortized cost 112 Corporate borrowings (1) Other liabilities Amortized cost 2,552 Non-recourse borrowings (1) Other liabilities Amortized cost 9,214 Includes both current and non-current portions. Investments in equity securities were originally referred to as available-for-sale securities in the 2017 annual consolidated financial statements. Derivative financial instruments comprise of energy derivative contracts, interest rate swaps and foreign exchange swaps. The classification and measurement requirements of IFRS 9 did not have a significant impact to Brookfield Renewable. Brookfield Renewable continued measuring at fair value all financial assets previously held at fair value under IAS 39. There are no changes in classification and measurement for Brookfield Renewable’s financial liabilities and there have been no financial liabilities designated at fair value through profit or loss. Impairment From January 1, 2018, Brookfield Renewable as sesses on a forward-looking basis the expected credit losses (“ECL”) associated with its assets carried at amortized cost and FVOCI, including finance lease receivables. For trade receivables only, Brookfield Renewable applies the simplified approach permi tted by IFRS 9, which requires expected lifetime losses to be recognized from initial recognition of the receivables. The simplified approach to the recognition of ECL does not require entities to track the changes in credit risk; rather, entities recogniz e a loss allowance at each reporting date based on the lifetime ECL since the date of initial recognition of the trade receivable. Evidence of impairment may include: Indications that a debtor or group of debtors is experiencing significant financial diff iculty; A default of delinquency in interest or principal payments; Probability that a debtor or a group of debtors will enter into bankruptcy or other financial reorganization; Changes in arrears or economic conditions that correlate with defaults, where observable data indicates that there is a measurable decrease in the estimated future cash flows. Trade receivables are reviewed qualitatively on a case by case basis to determine if they need to be written off. ECL are measured as the difference in the pr esent value of the contractual cash flows that are due under contract and the cash flows expected to be received. ECL is measured by considering the risk of default over the contract period and incorporates forward looking information into its measurement. Measurement of ECL on financial assets resulted in immaterial amounts; therefore, an allowance for doubtful accounts was not recorded. Derivatives and hedge accounting Before January 1, 2018, hedge documentation included identification of the hedging ins trument, the hedged item or transaction, the nature of the risk being hedged and how Brookfield Renewable will assess the effectiveness of changes in the hedging instrument’s fair value in offsetting the exposure to changes in the hedged item’s fair value or cash flows attributable to the hedged risk. Such hedges were expected to be highly effective in achieving offsetting changes in fair value or cash flows and were assessed on an ongoing basis to determine that they had actually been highly effective thro ughout the financial reporting periods for which they were designated. Beginning January 1, 2018, the documentation includes identification of the hedging instrument, the hedged item, the nature of the risk being hedged and how Brookfield Renewable will as sess whether the hedging relationship meets the hedge effectiveness requirements (including the analysis of sources of hedge ineffectiveness and how the hedge ratio is determined). A hedging relationship qualifies for hedge accounting if it meets all of th e following effectiveness requirements: There is ‘an economic relationship’ between the hedged item and the hedging instrument. The effect of credit risk does not ‘dominate the value changes’ that result from that economic relationship. The hedge ratio of the hedging relationship is the same as that resulting from the quantity of the hedged item that Brookfield Renewable actually hedges and the quantity of the hedging instrument that Brookfield Renewable actually uses to hedge that quantity of hedged item. Refer to Note 1(k) – Financial Instruments for details of Brookfield Renewable’s accounting policies for hedge accounting from January 1, 2018 under IFRS 9. (e) Foreign currency translation All figures reported in the consolidated financial statements and tabular disclosures to the consolidated financial statements are reflected in millions of U.S. dollars, which is the functional currency of Brookfield Renewable. Each of the foreign operations included in these consolidated financial statements determines its own functional currency, and items included in the financial statements of each subsidiary are measured using that functional currency. Assets and liabilities of foreign operations having a functional currency other than the U.S. dollar are translated at the rate of exchange prevailing at the reporting date and revenues and expenses at the rate of exchange prevailing at the dates of the transactions during the period. Gains or losses on translation of foreign subsidiaries are included in OCI. Gains or losses on foreign currency denominated balances and transactions that are designated as hedges of net investments in these operations are reported in th e same manner. In preparing the consolidated financial statements of Brookfield Renewable, foreign currency denominated monetary assets and liabilities are translated into the functional currency using the closing rate at the applicable consolidated statem ent of financial position dates. Non-monetary assets and liabilities, denominated in a foreign currency and measured at fair value, are translated at the rate of exchange prevailing at the date when the fair value was determined and non-monetary assets mea sured at historical cost are translated at the historical rate. Revenues and expenses are measured in the functional currency at the rates of exchange prevailing at the dates of the transactions with gains or losses included in income. (f) Cash and cash e quivalents Cash and cash equivalents include cash, term deposits and money market instruments with original maturities of less than 90 days. (g) Restricted cash Restricted cash includes cash and cash equivalents, where the availability of funds is restric ted primarily by credit agreements. (h) Property, plant and equipment and revaluation method Power generating assets are classified as property, plant and equipment and are accounted for using the revaluation method under IAS 16, Property, Plant and Equipm ent (“IAS 16”). Property, plant and equipment are initially measured at cost and subsequently carried at their revalued amount, being the fair value at the date of the revaluation, less any subsequent accumulated depreciation and any subsequent accumulated impairment losses. Brookfield Renewable generally determines the fair value of its property, plant and equipment by using a 20-year discounted cash flow model for the majority of its assets . This model incorporates future cash flows from long-term power purchase agreements that are in place where it is determined that the power purchase agreements are linked specifically to the related power generating assets. The model also includes estimates of future electricity prices, anticipated long-term average generation, estimated operating a nd capital expenditures, and assumptions about future inflation rates and discount rates by geographical location. Construction work-in-progress (“CWIP”) is revalued when sufficient information exists to determine fair value using the discounted cash flow method. Revaluations are made on an annual basis as at December 31 to ensure that the carrying amount does not differ significantly from fair value. For power generating assets acquired through business combinations during the year, Brookfield Renewable in itially measures the assets at fair value consistent with the policy described in Note 1(n) – Business combinations. Accordingly, in the year of acquisition, power generating assets are not revalued at year-end unless there is an indication that assets are impaired. Where the carrying amount of an asset increased as a result of a revaluation, the increase is recognized in income to the extent the increase reverses a previously recognized decrease recorded through income, with the remainder of the increase r ecognized in OCI and accumulated in equity under revaluation surplus and non-controlling interest. Where the carrying amount of an asset decreased, the decrease is recognized in OCI to the extent that a balance exists in revaluation surplus with respect to the asset, with the remainder of the decrease recognized in income. Depreciation on power generating assets is calculated on a straight-line basis over the estimated service lives of the assets, which are as follows: Estimated service lives Dams Up to 115 years Penstocks Up to 60 years Powerhouses Up to 115 years Hydroelectric generating units Up to 115 years Wind generating units Up to 30 years Solar generating units Up to 30 years Gas-fired cogenerating (“Cogeneration”) units Up to 40 years Other assets Up to 60 years Costs are allocated to significant components of property, plant and equipment. When items of property, plant and equipment have different useful lives, they are accounted for as separate items (significant components) and depreciated separately. To ensure the accuracy of useful lives and residual values, a review is conducted annually. Depreciation is calculated based on the cost of the asset less its residual value. Depreciation commences when the asset is in the location and condit ions necessary for it to be capable of operating in the manner intended by management. It ceases at the earlier of the date the asset is classified as held-for-sale and the date the asset is derecognized. An item of property, plant and equipment and any si gnificant component is derecognized upon disposal or when no future economic benefits are expected from its use. Other assets include equipment, buildings and leasehold improvements. Buildings, furniture and fixtures, leasehold improvements and office equi pment are recorded at historical cost, less accumulated depreciation. Land and CWIP are not subject to depreciation. The depreciation of property, plant and equipment in Brazil is based on the duration of the authorization or the useful life of a concess ion asset. The weighted-average remaining duration at December 31, 2018 is 29 years ( 2017 : 15 years). Since land rights are part of the concession or authorization, this cost is also subject to depreciation. In June of 2018, the federal government of Brazil provided further clarification to a law that was passed in 2016, which resulted in Brookfield Renewable including a one-time thirty year concession renewal period in the valuation of certain of its hydroelectric facilities in Brazil. Any accumul ated depreciation at the date of revaluation is eliminated against the gross carrying amount of the asset, and the net amount is applied to the revalued amount of the asset. Gains and losses on disposal of an item of property, plant and equipment are recog nized in Other income in the consolidated statements of income. The revaluation surplus is reclassified within the respective components of equity and not reclassified to net income when the assets are disposed. (i) Asset impairment At each statement of fi nancial position date, management assesses whether there is any indication that assets are impaired. For non-financial tangible and intangible assets (including equity-accounted investments), an impairment is recognized if the recoverable amount, determine d as the greater of the estimated fair value, less costs to sell, and the discounted future cash flows generated from use and eventual disposal of an asset or cash-generating unit, is less than its carrying value. The projections of future cash flows take into account the relevant operating plans and management’s best estimate of the most probable set of conditions anticipated to prevail. Should an impairment loss subsequently reverse, the carrying amount of the asset is increased to the lesser of the revis ed estimate of the recoverable amount, and the carrying amount that would have been recorded had no impairment loss been recognized previously. (j) Trade receivables and other current assets Trade receivables and other current assets are recognized initial ly at fair value, and subsequently measured at amortized cost using the effective interest method, less any provision for expected credit losses. (k) Financial instruments The following accounting policies are applicable to the accounting for financial in struments from January 1, 2018 under IFRS 9 . The impact to the Consolidated Financial Statements of the adoption of IFRS 9 in the current period and comparison to IAS 39 applied in the comparati ve period is explained in Note 1 (d) - Changes to and I mpact of F inancial I nstrument A ccounting P olicies . Initial recognition Under IFRS 9, regular purchases and sales of financial assets are recognized on the trade date, being the date on which Brookfield Renewable commits to purchase or sell the asset. Financial assets are derecognized when the rights to receive cash flows from the financial assets have expired or have been transferred and Brookfield Renewable has transferred substantially all the risks and rewards of ownership. At initial recognition, Brookfield Renewable measures a financial asset at its fair value. In the case of a financial asset not categorized as FVPL, transaction costs that are directly attributable to the acquisition of the financial asset are included at initial recognition. Transaction co sts of financial assets carried at FVPL are expensed in profit or loss. Classification and measurement Subsequent measurement of financial assets depends on Brookfield Renewable’s business objective for managing the asset and the cash flow characteristics of the asset. There are three measurement categories into which Brookfield Renewable classifies its financial assets: Amortized cost – Financial a ssets held for collection of contractual cash flows that represent solely payments of principal and interest a re measured at amortized cost. Interest income is recognized as other income in the financial statements, and gains/losses are recognized in profit or loss when the asset is derecognized or impaired. FVOCI – Financial a ssets held to achieve a particular bu siness objective other than short - term trading are designated at FVOCI. Unlike debt instruments designated at FVOCI, there is no recycling of gains or losses through profit and loss. Upon derecognition of the asset, accumulated gains or losses are transfer red from OCI directly to retained earnings. FVPL – Financial assets that do not meet the criteria for amortized cost or FVOCI are measured at FVP L. Financial liabilities are classified as financial liabilities at fair value through profit and loss, amortiz ed cost, or derivatives designated as hedging instruments in an effective hedge. Brookfield Renewable determines the classification of its financial liabilities at initial recognition. Brookfield Renewable’s financial liabilities include accounts payable a nd accrued liabilities, corporate borrowings, non-recourse borrowings, derivative liabilities, and due to related party balances. Financial liabilities are initially measured at fair value, with subsequent measurement determined based on their classificati on as follows: FVPL – Financial liabilities held for trading, such as those acquired for the purpose of selling in the near term, and derivative financial instruments entered into by Brookfield Renewable that do not meet hedge accounting criteria are class ified as fair value through profit and loss. Gains or losses on th ese type s of liabilities are recognized in profit and loss. Amortized cost – All other financial liabilities are classified as amortized cost using the effective interest rate method. Gains and losses are recognized in profit and loss when the liabilities are derecognized as well as through the amortization process. Amortized cost is computed using the effective interest method less any principal repayment or reduction. The calculation takes into account any premium or discount on acquisition and includes transaction costs and fees that are an integral part of the effective interest rate. This category includes trade and other payables, dividends payable, interest-bearing loans and borrowings, and corporate credit facilities. Derivatives and hedge accounting Derivatives are initially recognized at fair value on the date a derivative contract is entered into and are subsequently remeasured to their fair value at the end of each reporting period. The accounting for subsequent changes in fair value depends on whe ther the derivative is designated as a hedging instrument, and if so, the nature of the item being hedged and the type of hedge relationship designated. Brookfield Renewable designates its derivatives as hedges of: Foreign exchange risk associated with t he cash flows of highly probable forecast transactions (cash flow hedges); Foreign exchange risk associated with net investment in foreign operations (net investment hedges); Commodity price risk associated with cash flows of highly probable forecast tra nsactions (cash flow hedges); and Floating interest rate risk associated with payments of debts (cash flow hedges). The fair values of various derivative financial instruments used for hedging purposes and movements in the hedge reserve within equity are shown in Note 5 – Risk Management and Financial Instruments . When a hedging instrument expires, is sold, is terminated, or no longer meets the criteria for hedge accounting, any cumulative deferred gain or loss and deferred costs of hedging in equity at that time remain in equity until the forecasted transaction occurs. When the forecasted transaction is no longer expected to occur, the cumulative gain or loss and deferred costs of hedging are immediately reclassified to profit and loss. If the hedge ratio for risk management purposes is no longer optimal but the risk management objective remains unchanged and the hedge continues to qualify for hedge accounting, the hedge relationship will be rebalanced by adjusting either the volume of the hedging ins trument or the volume of the hedged item so that the hedge ratio aligns with the ratio used for risk management purposes. Any hedge ineffectiveness is calculated and accounted for in profit and loss at the time of the hedge relationship rebalancing. (i) Cash flow hedges that qualify for hedge accounting The effective portion of changes in the fair value of derivatives that are designated and qualify as cash flow hedges is recognized in the cash flow hedge reserve within equity, limited to the cumulati ve change in fair value of the hedged item on a present value basis from the inception of the hedge. The gain or loss relating to the ineffective portion is recognized immediately in profit and loss, within unrealized financial instruments gain (loss) . Ga ins and losses relating to the effective portion of the change in fair value of the entire forward contract are recognized in the cash flow hedge reserve within equity. Amounts accumulated in equity are reclassified in the period when the hedged item affec ts profit and loss. (ii) Net investment hedg es that qualify for hedge accounting Hedges of net investments in foreign operations are accounted for similarly to cash flow hedges. Any gain or loss on the hedging instrument relating to the effective porti on of the hedge is recognized in OCI and accumulated in reserves in equity. The gain or loss relating to the ineffective portion is recognized immediately in profit and loss within foreign exchange and unrealized financial instruments gain (loss) . Gains an d losses accumulated in equity will be reclassified to profit and loss when the foreign operation is partially disposed of or sold. (iii) Hedge ineffectiveness Brookfield Renewable’s hedging policy only allows for the use of derivative instruments that form effective hedge relationships. Hedge effectiveness is determined at the inception of the hedge relationship and through periodic prospective effectiveness assessments to ensure that an economic relationship exists between the hedged item and hedging instrument. Where the critical terms of the hedging instrument match exactly with the terms of the hedged item, a qualitative assessment of effectiveness is performed. For other hedge relationships, the hypothetical derivative method to assess effectivenes s is used. (l) Revenue and expense recognition The majority of revenue is derived from the sale of power and power related ancillary services both under contract and in the open market, sourced from Brookfield Renewable’s power generating facilities. The obligations are satisfied over time as the customer simultaneously receives and consumes benefits as Brookfield Renewable delivers el ectricity and related products. Revenue is recorded based upon the output delivered and capacity provided at rates specified under either contract terms or prevailing market rates. The revenue reflects the consideration Brookfield Renewable expects to be e ntitled to in exchange for those goods or services. Costs related to the purchases of power or fuel are recorded upon delivery. All other costs are recorded as incurred. Details of the revenue recognized per geographical region are included in Note 6

PRINCIPAL SUBSIDIARIES

PRINCIPAL SUBSIDIARIES	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
PRINCIPAL SUBSIDIARIES	2 . PRINCIPAL SUBSIDIARIES The following table lists the subsidiaries of Brookfield Renewable which, in the opinion of management, significantly affect its financial position and results of operations as at December 31, 2018 : Jurisdiction of Percentage of Incorporation voting securities or Organization owned or controlled (%) Alta Wind VIII LLC (1) Delaware 100 BIF II Safe Harbor Holdings LLC (1) Delaware 100 BIF III Holtwood LLC (1) Delaware 100 BRE GLBL Holdings L.P. (1) Bermuda 100 BRI Green Energy Limited (1) Republic of Ireland 100 Brookfield BRP Canada Corp. Alberta 100 Brookfield Energia Comercializadora Ltda Brazil 100 Brookfield Power US Holding America Co. Delaware 100 Brookfield Renewable UK Hydro Limited England and Wales 100 Brookfield Smoky Mountain Hydropower LLC (1) Delaware 100 Brookfield White Pine Hydro LLC (1) Delaware 100 Catalyst Old River Hydroelectric Limited Partnership (2) Louisiana 75 Erie Boulevard Hydropower, L.P. Delaware 100 Great Lakes Hydro America, LLC Delaware 100 Great Lakes Power Limited Ontario 75 Hawks Nest Hydro LLC Delaware 100 Isagen S.A. E.S.P. (1) Colombia 99.5 Kwagis Power Limited Partnership British Columbia 75 Lièvre Power L.P. Québec 100 Mississagi Power Trust Québec 100 Orion Canadian Holdings 1 AIV L.P. Ontario 100 Powell River Energy Inc. Canada 100 Rumford Falls Hydro LLC Delaware 100 Safe Harbor Water Power Corporation (1) Pennsylvania 100 Tangará Energia S.A. (1) Brazil - São Paulo 100 Windstar Energy, LLC California 100 2016 Comber Wind Limited Partnership Ontario 100 Voting control held through voting agreements with Brookfield. Non-voting economic interest held through preferred shares and secured notes.

ACQUISITIONS

ACQUISITIONS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
ACQUISTIONS	3 . ACQUISITIONS The following investment s w ere accounted for using the acquisition method, and the results of operations have been included in the consolidated financial statements since the date of acquisition. Biotherm Brookfield Renewable previously acquired TerraForm Global, Inc. (“ TerraForm Global ”) on December 28th, 2017 . Included in the net identifiable assets of TerraForm Global was $ 56 million in restricted cash and deposit s for the acquisition of controlling inte rests (ranging between 65 % and 70 %) in three separate companies that cumulatively operate 49 MW of wind and solar assets in South Africa (“Biotherm”) . In March 2018, Brookfield Renewable acquired Biotherm for a total consideration of $ 71 million. This amou nt was transferred in two tranches and include d the aforementioned deposit, a cash payment of $ 12 million and d eferred consideration of $ 3 million. The total acquisition costs of less than $ 1 million were expensed as incurred and have been classified under Other in the consolidated statement of income (loss). Northern Ireland Wind In March 2018, Brookfield Renewable entered into an agreement to acquire, along with its institutional partners, a 100 % interest in a 23 MW wind facility in Northern Ireland (“ Northern Ireland Wind ”). In October 2018, Brookfield Renewable, along with its institutional partners, completed the acquisition of Northern Ireland Wind. The total consideration was £ 22 million ($ 28 million). Brookfield Renewable retains an approximate 40 % controlling interest. The total acquisition costs of less than $ 1 million were expensed as incurred and have been classified under Other in the consolidated statement of income (loss). Northern Ireland (MILLIONS) Note Biotherm Wind Total Cash and cash equivalents $ 12 $ 1 $ 13 Trade receivables and other current assets 7 - 7 Property, plant and equipment, at fair value 158 53 211 Current liabilities (3) (4) (7) Current portion of non-recourse borrowings (3) - (3) Financial instruments (2) - (2) Non-recourse borrowings (69) (18) (87) Deferred income tax liabilities (35) (4) (39) Non-controlling interests (21) - (21) Fair value of net assets acquired 44 28 72 Goodwill 17 27 - 27 Purchase price $ 71 $ 28 $ 99 Completed in 2017 The following investment s were accounted for using the equity method as Brookfield Renewable has significant influence through its position in the business, and the results of operations have been included in the audited annual consolidated financial statements since the date of investment . European Storage In August 2017 , Brookfield Renewable, along with its institutional partners, acquired a 25 % interest in FHH Guernsey Ltd which owns a 2.1 GW pumped storage portfolio in the Un ited Kingdom (“European Storage”) . Brookfield Renewable retains an approximate 7 % economic interest in the portfolio. Total consideration was £ 194 million ($ 248 million). The acquisition costs of £1 million ($1 million) were incurred and capitalized. TerraForm Power In October 2017 , along with its institutional partners, Brookfield Renewable closed the acquisition of a 51% interest in TerraForm Power, Inc . (“TerraForm Power”). TerraForm Power is a 2,600 MW large scale diversified portfolio of solar and wind assets located predominately in the U.S. Brookfield Renewable retains an indirect economic interest of approximately 16 % in TerraForm Power for a total net investment of $ 203 million. Brookfield Renewable had previously accounted for its indirect in terest in TerraForm Power as an available for sale investment. The change from available for sale accounting to equity method accounting resulted in a gain of $ 13 million being reclassified from the audited annual consolidated statement of comprehensive in come to the statement of income and included in Other income, representing the accumulated gain on the previously held indirect investment. The acquisition costs of $ 1 million were incurred and capitalized . In October 2017, Brookfield Renewable entered int o a voting agreement with the Brookfield subsidiary that ultimately controls TerraForm Power. Pursuant to this voting agreement, Brookfield Renewable is entitled to direct the election for one of the four directors of the Brookfield subsidiary, thereby pro viding Brookfield Renewable with significant influence over this subsidiary . The following investment s w ere accounted for using the acquisition method, and the results of operations have been included in the audited annual consolidated financial statements since the date of acquisition. European Wind In February 2017 , Brookfield Renewable entered into an agreement to acquire, along with its institutional partners, a 100 % interest in a 16 MW wind facility in Northern Ireland (“ European Wind ”). In August 2017 , Brookfield Renewable, along with its institutional partners, completed the acquisition of European Wind, which was commissioned in July of 2017. I f the acquisition had taken place at the beginning of the y ear, the revenue from European Wind earned prior to the date of acquisition would have been immaterial. The total consideration was £ 24 million ($ 32 million). Brookfield Renewable retains an approximate 40% controlling interest in the asset. The total acqu isition costs of less than $ 1 million were expensed as incurred and have been classified under Other in the audited annual consolidated statements of income. TerraForm Global In December 2017 , along with its institutional partners, Brookfield Renewable closed the acquisition of a 100% interest in TerraForm Global . TerraForm Global is a 919 MW portfolio of diversified solar and wind assets located predominately in Brazil and Asia. The total con sideration paid was $ 657 million and the fair value of the interest previously held was $ 100 million. Brookfield Renewable retains a 31 % economic interest in TerraForm Global with its share of t he fair value of previously held interest on the acquisition d ate totaling $ 30 million. Brookfield Renewable’s share of the consideration paid was $ 202 million. Brookfield Renewable had previously accounted for its indirect interest in TerraForm Global as an available for sale investment. The change from available fo r sale accounting to consolidation accounting resulted in a gain of $ 2 million being reclassified from the audited annual consolidated statement of comprehensive income to the statement of income and included in Other income, representing the accumulated g ain on the previously held indirect investment. If the acquisition had taken place at the beginning of the year, the revenue from TerraForm Global for the year ended December 31, 2017 would have been $ 250 million. The total acquisition costs of $ 1 million were expensed as incurred and have been classified under Other in the audited annual consolidated statements of income. In December 2017, Brookfield Renewable entered into a voting agreement with an affiliate of Brookfield Renewable that ultimately controls TerraForm Global. Pursuant to this voting agreement, Brookfield Renewable is entitled to direct the election of the directors of the Brookfield subsidiary. Purchase price allocations Final purchase price allocations, at fair value, with respect to the acquisitions completed in 2017 are as follows: TerraForm European (MILLIONS) Global Wind Total Cash and cash equivalents $ 611 $ - $ 611 Restricted cash 90 - 90 Trade receivables and other current assets 62 1 63 Financial instruments 20 - 20 Property, plant and equipment, at fair value 1,208 37 1,245 Deferred tax assets 18 - 18 Other long-term assets 94 - 94 Current liabilities (73) (4) (77) Current portion of non-recourse borrowings (1,183) - (1,183) Financial instruments (15) - (15) Non-recourse borrowings (5) - (5) Deferred income tax liabilities (15) (2) (17) Other long-term liabilities (54) - (54) Non-controlling interests (1) - (1) Fair value of net assets acquired $ 757 $ 32 $ 789 Completed in 2016 The following investments were accounted for using the acquisition method, and the results of operations have been included in the audited annual consolidated financial statements since the respective dates of acquisition. Colombia Portfolio On January 22, 2016, Brookfield Renewable and its institutional partners (the “consortium”) acquired a 57.6 % interest in Isagen S.A. E.S.P (“Isagen”) from the Colombian government (the “Initial Investment”). Isagen was a listed entity in Colombi a. It is Colombia’s third-largest power generation company and owns and operates a 3,032 MW portfolio, consisting predominantly of a portfolio of largely reservoir-based, hydroelectric facilities. Annual generation is expected to approximate 15,000 GWh. F ollowing the closing of the Initial Investment, the consortium was required to conduct two mandatory tender offers (“MTOs”) for the Isagen public shareholders at the same price per share paid for its initial 57.6% controlling interest. The consortium clos ed the First MTO and the Second MTO on May 13, 2016 and September 14, 2016, respectively. During 2017, the consortium acquired further shares from public shareholders and completed delisting of Isagen from the Colombia Stock Exchange. After giving effect to the MTOs and additional shares the consortium ownership stands at 99.5 % as of December 31, 2018. Brookfield Renewable is the general partner of and controls the entity that holds the consortium’s 99 .5% interest in Isagen. Brookfield Renewable’s investment is equivalent to an approximate 24% economic interest. The total acquisition costs of $ 13 million were expensed as incurred and have been classified under Other in the audited annual consolidated s tatements of income in 2016. If the acquisition had taken place at the beginning of the year, the revenue from Isagen for the year ended December 31, 2016 would have been $ 900 million. Brazil Portfolio In January 2016 , Brookfield Renewable acquired a 51 MW hydroelectric portfolio in Brazil (“Brazil Portfolio”). Total consideration of R$ 417 million ($ 103 million) included cash paid of R$ 355 million ($ 88 million), deferred consideration of R$ 35 million ($ 9 million) and the impact of the foreign currency con tracts of R$ 24 million ($ 6 million). Brookfield Renewable retains a 100 % interest in the portfolio. The total acquisition costs of less than $ 1 million were expensed as incurred and classified under Other in the audited annual consolidated statements of in come in 2016. North American Portfolio In April 2016 , Brookfield Renewable acquired a 296 MW portfolio of hydroelectric facilities in Pennsylvania that are expected to generate 1,109 GWh annually (“ Pennsylvania Hydro ”). The acquisition was completed with institutional partners, and Brookfield Renewable retains approximately 28.6% interest in the portfolio. Total cash consideration was $ 859 million. The acquisition costs of $ 6 million were expensed as incurred and have been classified under Other in the aud ited annual consolidated statements of income in 2016. If the acquisition had taken place at the beginning of the year, the revenue from Pennsylvania Hydro for the year ended December 31, 2016 would have been $ 46 million. In April 2016, Brookfield Renewab le entered into a voting agreement with a Brookfield subsidiary that forms part of Brookfield Infrastructure Fund III. Pursuant to this voting agreement, Brookfield Renewable is entitled to direct the election of the directors of the entity that ultimately controls and operates the Pennsylvania Hydro assets. European Wind Development Project In September 2016 , Brookfield Renewable acquired a 19 MW wind development project in Ireland. The total consideration of € 8 million ($ 9 million) included cash consid eration of € 7 million ($ 8 million) and deferred consideration and working capital adjustments of € 1 million ($ 1 million). The acquisition was completed with institutional partners, and Brookfield Renewable retained an approximately 40 % controlling interest in the asset. The total acquisition costs of less than $ 1 million were expensed as incurred and have been classified under Other in the audited annual consolidated statements of income. Purchase price allocations Final purchase price allocations, at fair value, with respect to the acquisitions completed in 2016 are as follows: (MILLIONS) Colombia Brazil Pennsylvania Ireland Total Cash and cash equivalents $ 113 $ 4 $ - $ - $ 117 Trade receivables and other current assets 174 2 1 - 177 Property, plant and equipment, at fair value 4,772 100 859 10 5,741 Other long-term assets 15 - - - 15 Current liabilities (463) (3) (1) - (467) Non-recourse borrowings (899) - - - (899) Deferred income tax liabilities (1,019) - - (1) (1,020) Other long-term liabilities (149) - - - (149) Non-controlling interests (1,417) - - - (1,417) Fair value of net assets acquired 1,127 103 859 9 2,098 Goodwill 799 - - - 799 Purchase price $ 1,926 $ 103 $ 859 $ 9 $ 2,897 During the years ended December 31, 2018 and 2017 , the purchase price allocations for the acquisitions in 2017 and 2016 , respectively, were finalized. No material changes to the provisional purchase price allocations disclosed in the audited annual consolidated financial statements for 2017 and 2016 had to be considered for acquisitions made in the respective years.

ASSETS HELD FOR SALE

ASSETS HELD FOR SALE	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
ASSETS HELD FOR SALE	4 . assets held for sale The following is a summary of the major items of assets and liabilities classified as held for sale as at December 31, 2018: (MILLIONS) Total Assets Cash and cash equivalents $ 8 Restricted cash 47 Trade receivables and other current assets 28 Property, plant and equipment, at fair value 749 Goodwill 22 Other long-term assets 66 Assets held for sale $ 920 Liabilities Current liabilities $ 23 Non-recourse borrowings 360 Other long-term liabilities 150 Liabilities directly associated with assets held for sale $ 533 A revaluation of the property, plant, and equipment associated with the disposal groups discussed below was performed immediately prior to classification as held for sale in accordance with our accounting policy election to apply the revaluation method. The cumulative amount recognized in other comprehensive income relating to limited partners’ equity for the assets held for sale is $ 21 million. Brookfield Renewable continues to consolidate and recognize, in the consolidated statements of income (loss), consolidated statements of comprehensive income, and the consolidated statements of cash flows, the revenues, expenses and cash flows associated with assets held for sale. Non-current assets classified as held for sale are not depreciated. South Africa Portfolio In July 2018, Br ookfield Renewable, along with its institutional partners, entered into an agreement to sell its controlling interest in a 178 MW wind and solar portfolio in South Africa (“South Africa Portfolio”) for a total consideration of ZAR 2,031 million (approximat ely $ 166 million – Brookfield Renewable’s share totaling approximately $ 50 million). The transaction is subject to closing conditions, including regulatory and lender approvals. Brookfield Renewable holds a 31 % economic interest and 100 % voting interest in the South Africa Portfolio. The proportionate amount of consideration attributable to the institutional partners upon the closing of the transaction approximates their economic interest in the South Africa Portfolio. Each of the project entities included in the South Africa Portfolio contain additional non-controlling economic interest ranging between 30 % and 49 %. Thailand Portfolio In December 2018, Brookfield Renewable, along with its institutional partners, entered into an agreement to sell its controll ing interest in a 40 MW solar portfolio in Thailand (“Thailand Portfolio”) for a total consideration of THB 3,070 million (approximately $ 95 million – Brookfield Renewable’s share totaling approximately $ 29 million). The transaction is subject to the satis faction of closing conditions. The proportionate amount of consideration attributable to the institutional partners upon the closing of the transaction approximates their economic interest in the Thailand Portfolio. Brookfield Renewable holds a 31 % economi c interest and 100 % voting interest in the Thailand Portfolio. Malaysia Portfolio In December 2018, Brookfield Renewable, along with its institutional partners, entered into an agreement to sell its controlling interest in a 19 MW solar portfolio in Malay sia (“Malaysia Portfolio”) for a total consideration of MYR 154 million (approximately $ 37 million – Brookfield Renewable’s share totaling approximately $ 11 million). The transaction is subject to the satisfaction of closing conditions. Brookfield Renewabl e holds a 31 % economic interest and 100% voting interest in the Malaysia Portfolio. The proportionate amount of consideration attributable to the institutional partners upon the closing of the transaction approximates their economic interest in the Malaysi a Portfolio. Each of the project entities included in the Malaysia Portfolio contain additional non-controlling economic interest ranging between 5 % and 49 %.

RISK MANAGEMENT AND FINANCIAL I

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
RISK MANAGEMENT AND FINANCIAL INSTRUMENTS	5 . RISK MANAGEMENT AND FINANCIAL INSTRUMENTS RISK MANAGEMENT Brookfield Renewable’s activities expose it to a variety of financial risks, including market risk (i.e., commodity price risk, interest rate risk, and foreign currency risk), credit risk and liquidity risk. Brookfield Renewable uses financial instruments primarily to manage these risks. The sensitivity analysis discussed below reflect the risks associated with instruments that Brookfield Renewable considers are market sensitive and the potential loss resulting from one or more selected hypothetical changes. Therefore, the discussion below is not intended to fully reflect Brookfield Renewable’s risk exposure. (a) Market risk Market risk is defined for these purposes as the risk that the fair value or future cash flows of a financial instrument held by Brookfield Renewable will fluctuat e because of changes in market prices. Brookfield Renewable faces market risk from foreign currency assets and liabilities, the impact of changes in interest rates, and floating rate liabilities. Market risk is managed by funding assets with financial lia bilities in the same currency and with similar interest rate characteristics and holding financial contracts, such as interest rate swaps and foreign exchange contracts, to minimize residual exposures. Financial instruments held by Brookfield Renewable tha t are subject to market risk include borrowings and financial instruments, such as interest rate, currency and commodity contracts. The categories of financial instruments that can give rise to significant variability are described below: (i) Electricity p rice risk Electricity price risk is defined for these purposes as the risk that the fair value or future cash flows of a financial instrument held by Brookfield Renewable will fluctuate because of changes in electricity prices. Electricity price risk aris es from the sale of Brookfield Renewable’s uncontracted generation. Brookfield Renewable aims to sell electricity under long-term contracts to secure stable prices and mitigate its exposure to wholesale markets. The table below summarizes the impact of cha nges in the market price of electricity as at December 31. The impact is expressed in terms of the effect on net income and OCI. The sensitivities are based on the assumption that the market price changes by 5% with all other variables held const ant. Impact of a 5% change in the market price of electricity, on outstanding energy derivative contracts, for the year ended December 31: Effect on net income (1) Effect on OCI (1) (MILLIONS) 2018 2017 2016 2018 2017 2016 5% increase $ (3) $ (3) $ (1) $ (10) $ (4) $ (7) 5% decrease 3 3 1 10 4 7 Amounts represent the potential annual net pretax impact. (ii) Foreign currency risk Foreign currency risk is defined for these purposes as the risk that the fair value of a financial instrument held by Brookfield Renewable will fluctuate because of changes in foreign currency rates. Brookfield Renewable has exposure to the Canadian dollar, Brazilian real, Euro, British pound sterling, Colombian peso, Indian rupee, South African rand, Malaysian ringgit, Thai baht and Chinese yuan through its investments in foreign operations. Consequently, fluctuations in the U.S. dollar exchange rate against these currencies increase the volatility of net income and other comprehensive income. Brookfield Renewable holds foreign currency contracts primarily to mitigate this exposure. The table below summarizes the impact to Brookfield Renewable’s financial instruments of ch anges in the exchange rate as at December 31. The impact is expressed in terms of the effect on income and OCI. The sensitivities are based on the assumption that the currency exchange rate changes by five percent with all other variables held constant. Im pact of a 5% change in U.S. dollar exchange rates, on outstanding foreign exchange swaps, for the year ended December 31: Effect on net income (1) Effect on OCI (1) (MILLIONS) 2018 2017 2016 2018 2017 2016 5% increase $ 30 $ 4 $ 1 $ 44 $ 79 $ 51 5% decrease (30) (4) (1) (44) (79) (51) (iii) Interest rate risk Interest rate risk is defined for these purposes as the risk that the fair value or future cash flows of a financial instrument held by Brookfield Renewable will fluctuate, because of changes in interest rates. Brookfield Renewable’s assets largely consist of long duration physical assets. Brookfield Renewable’s financial liabilities consist primarily of long-term fixed rate debt or floating-rate debt that has been swapped to fixed rates with interest rate financial instrum ents. All non-derivative financial liabilities are recorded at their amortized cost. Brookfield Renewable also holds interest rate contracts to lock-in fixed rates on certain anticipated future debt issuances. Brookfield Renewable will enter into interest rate swaps designed to minimize the exposure to interest rate fluctuations on its variable rate debt. Fluctuations in interest rates could impact Brookfield Renewable’s cash flows, primarily with respect to the interest payable against Brookfield Renewable ’s variable rate debt, which is limited to certain non-recourse borrowings with a total principal value of $ 3,764 million ( 2017 : $ 4,176 million). Of this princ ipal value, $ 1,447 million ( 2017 : $ 824 million) has been hedged through the use of interest rate swaps. The fair values of the recognized liability for the interest rate swaps were calculated using a valuation model with observable interest rates . The table below summarizes the impact of changes in the interest rate as at December 31. The impa ct is expressed in terms of the effect on income and OCI. The sensitivities are based on the assumption that the interest rate changes by one percent with all other variables held constant. Impact of a 1% change in interest rates, on outstanding interest r ate swaps and variable rate debt, for the year ended December 31: Effect on net income (1) Effect on OCI (1) (MILLIONS) 2018 2017 2016 2018 2017 2016 1% increase $ (10) $ 17 $ (17) $ 42 $ 54 $ 115 1% decrease 11 (17) 17 (42) (54) (115) Amounts represent the potential annual net pretax impact. (b) Credit risk Credit risk is the risk of loss due to the failure of a borrower or counterparty to fulfill its contractual obligations. Brookfield Renewable’s exposure to credit risk in respect of financial instruments relates primarily to counterparty obligations regarding energy contracts, interest rate swaps, forward foreign exchange contracts and physical electricity and gas transactions. Brookfield Renewable minimizes credit risk with counterparties through the selection, monitoring a nd diversification of counterparties, and the use of standard trading contracts, and other credit risk mitigation techniques. In addition, Brookfield Renewable’s power purchase agreements are reviewed regularly and are almost exclusively with customers ha ving long standing credit histories or investment grade ratings, which limit the risk of non-collection. See Note 23 - Trade receivables and other current assets, for additional details regarding Brookfield Renewable’s trade receivables balance. The max imum credit exposure at December 31 was as follows: (MILLIONS) 2018 2017 Trade receivables and other short-term receivables 493 442 Due from related parties 65 60 Other long-term assets 402 - $ 960 $ 502 (c) Liquidity risk Liquidity risk is the risk that Brookfield Renewable cannot meet a demand for cash or fund an obligation when due. Liquidity risk is mitigated by Brookfield Renewable’s cash and cash equivalent balances and its access to undrawn credit facilities. Details of the available portion of credit facilities are included in Note 13 – Borrowings. Brookfield Renewable also e nsur es that it has access to public capital markets and maintain s a strong investment grade credit rating. Brookfield Ren ewable is also subject to the risk associated with debt financing. This risk is mitigated by the long-term duration of debt instruments and the diversification in maturity dates over an extended period of time. CASH OBLIGATIONS The table below classifies t he cash obligations related to Brookfield Renewable’s liabilities into relevant maturity groupings based on the remaining period from the statement of financial position dates to the contractual maturity date. As the amounts are the contractual undiscount ed cash flows (gross of unamortized financing fees and accumulated amortization, where applicable), they may not agree with the amounts disclosed in the consolidated statements of financial position. AS AT DECEMBER 31, 2018 (MILLIONS) < 1 year 2-5 years > 5 years Total Accounts payable and accrued liabilities $ 533 $ - $ - $ 533 Financial instrument liabilities (1) 27 57 54 138 Due to related parties 101 - - 101 Other long-term liabilities - concession payments 1 4 10 15 Corporate borrowings (1) 6 1,344 990 2,340 Non-recourse borrowings (1) 489 2,806 5,164 8,459 Interest payable on borrowings (2) 577 1,906 1,684 4,167 Total $ 1,734 $ 6,117 $ 7,902 $ 15,753 AS AT DECEMBER 31, 2017 (MILLIONS) < 1 year 2-5 years > 5 years Total Accounts payable and accrued liabilities $ 542 $ - $ - $ 542 Financial instrument liabilities (1) 184 62 24 270 Due to related parties 112 - - 112 Other long-term liabilities - concession payments 1 3 10 14 Corporate borrowings (1) 159 1,563 835 2,557 Non-recourse borrowings (1) 1,517 3,024 4,744 9,285 Interest payable on borrowings (2) 634 1,924 1,697 4,255 Total $ 3,149 $ 6,576 $ 7,310 $ 17,035 Includes both the current and long-term amounts. Represents aggregate interest payable expected to be paid over the entire term of the obligations, if held to maturity. Variable rate interest payments have been calculations based on estimated interest rates. Fair value disclosure s Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair values determined using valuation models require the use of assumptions concerning the amount and timing of estimated future cash flows and discount rates. In determining those assumptions, management looks primarily to external readily observable market inputs such as interest rate yield curves, currency rates, commodity prices and, as applicable, credit spreads. A fair value measurement of a non-financial asset is the consideration that would be received in an orderly transaction between market participants, considering the highest and best use of the asset. Assets and liabilities measured at fair value are categorized into one of three hierarchy levels, described below. Each level is based on the transparency of the inputs used to measure the fair values of assets and liabilities. Level 1 – inp uts are based on unadjusted quoted prices in active markets for identical assets and liabilities; Level 2 – inputs, other than quoted prices in Level 1, that are observable for the asset or liability, either directly or indirectly; and Level 3 – inputs for the asset or liability that are not based on observable market data . The following table presents Brookfield Renewable’s assets and liabilities measured and disclosed at fair value classified by the fair value hierarchy as at December 31: (MILLIONS) Level 1 Level 2 Level 3 2018 2017 Assets measured at fair value: Cash and cash equivalents $ 173 $ - $ - $ 173 $ 799 Restricted cash (1) 181 - - 181 284 Financial instrument assets (2)(3) Energy derivative contracts - 3 - 3 - Interest rate swaps - 9 - 9 6 Foreign exchange swaps - 55 - 55 20 Investments in equity securities (2) 60 57 - 117 159 Property, plant and equipment - - 29,025 29,025 27,096 Liabilities measured at fair value: Financial instrument liabilities (3) Energy derivative contracts - (22) - (22) (19) Interest rate swaps - (116) - (116) (155) Foreign exchange swaps - - - - (96) Contingent consideration (4) - - (3) (3) (18) Assets for which fair value is disclosed: Equity-accounted investments (5) 703 - - 703 278 Liabilities for which fair value is disclosed: Corporate borrowings (1,640) (727) - (2,367) (2,641) Non-recourse borrowings (370) (8,326) - (8,696) (9,838) Total $ (893) $ (9,067) $ 29,022 $ 19,062 $ 15,875 Includes both the current amount and long-term amount included in Other long-term assets. Amounts in Level 2 include Brookfield Infrastructure Debt Fund holdings. Includes both current and long-term amounts. Amount relates to business combinations with obligations lapsing in 2021 and 2024. The fair value corresponds to Brookfield Renewable’s investment in publicly-quoted common shares of TerraForm Power, Inc . There were no transfers between levels during the year ended December 31, 2018 . Financial instruments disclosures The aggregate amount of Brookfield Renewable’s net financial instrument positions as at December 31 are as follows: 2018 2017 Net Assets Net Assets (MILLIONS) Assets Liabilities (Liabilities) (Liabilities) Energy derivative contracts $ 3 $ 22 $ (19) $ (19) Interest rate swaps 9 116 (107) (149) Foreign exchange swaps 55 - 55 (76) Investments in equity securities 117 - 117 159 Total 184 138 46 (85) Less: current portion 60 27 33 (112) Long-term portion $ 124 $ 111 $ 13 $ 27 The following table presents the change in Brookfield Renewable’s total net financial instrument asset position as at and for the year ended December 31: (MILLIONS) Note 2018 2017 2016 Balance, beginning of year $ (85) $ (28) $ (145) Increases (decreases) in the net financial instrument liability position: Unrealized (loss) gain through OCI on investments in equity securities (a) (16) (20) 52 Unrealized (loss) through income on energy derivative contracts (b) (3) (5) - Unrealized (loss) through OCI on energy derivative contracts (b) - (17) (28) Unrealized gain (loss) through income on interest rate swaps (c) 17 1 (7) Unrealized gain (loss) through OCI on interest rate swaps (c) 14 18 (1) Unrealized gain (loss) through income on foreign exchange swaps (d) 76 (29) 3 Unrealized gain (loss) through OCI on foreign exchange swaps (d) 87 (94) (61) Acquisitions, settlements and other (44) 89 159 Balance, end of year $ 46 $ (85) $ (28) Financial instrument assets designated at fair value through OCI Investments in equity securities (a) 117 159 136 Derivative assets not designated as hedging instruments: Energy derivative contracts (b) $ 3 $ - $ 3 Interest rate swaps (c) - 1 1 Foreign exchange swaps (d) 32 19 10 Net positions $ 35 $ 20 $ 14 Derivative assets designated as hedging instruments: Energy derivative contracts (b) $ - $ - $ 5 Interest rate swaps (c) 9 5 6 Foreign exchange swaps (d) 23 1 39 Net positions $ 32 $ 6 $ 50 Derivative liabilities not designated as hedging instruments: Energy derivative contracts (b) $ (7) $ (5) $ (3) Interest rate swaps (c) (82) (107) (2) Foreign exchange swaps (d) - (33) (6) Net positions $ (89) $ (145) $ (11) Derivative liabilities designated as hedging instruments: Energy derivative contracts (b) $ (15) $ (14) $ (2) Interest rate swaps (c) (34) (48) (176) Foreign exchange swaps (d) - (63) (39) Net positions $ (49) $ (125) $ (217) Total financial instruments, net $ 46 $ (85) $ (28) (a) Investments in equity securities Investments in equity securities are held to achieve a particular business objective other than short-term trading and are designated at fair value through OCI. There is no recycling of gains or losses through profit or loss. Upon derecognition of the associated asset, accumulated gains or losses are transferred from OCI directly to retained earnings. In the comparative periods presented in accordance with IAS 39, investments in equity securities were classified as av ailable-for-sale securities and were assessed for impairment at each reporting date. For the year ended December 31, 2017, gains of $ 2 million (2016: gains of $ 9 million) relating to available-for-sale securities were reclassified from OCI to net income. ( b ) Energy derivative contracts Brookfield Renewable has entered into long-term energy derivative contracts primarily to stabilize or eliminate the price risk on the sale of certain future power generation. Certain energy contracts are recorded in Brookfield Renewable’s consolidated financial statements at an amount equal to fair value, using quoted market prices or, in their absence, a valuation model using both internal and third-party evidence and forecasts. There is an economic relationship betw een the hedged items and the hedging instruments as the terms of the energy derivative contracts match the terms of the expected highly probable forecast transactions (i.e. notional amount and expected payment date). Brookfield Renewable has established a hedge ratio of 1:1 for the hedging relationships as the underlying risk of the energy derivative contracts are identical to the hedged risks. To test the hedge effectiveness, Brookfield Renewable uses the hypothetical derivative method and compares changes in the fair value of the hedging instruments against the changes in fair value of the hedged items attributable to the hedged risks. The hedge ineffectiveness can arise from different indexes (and accordingly different curves) linked to the hedged risk of the hedged items and hedging instruments. For the year ended December 31, 2018 , losses of $ 6 million relating to energy derivative contracts were realized and reclassified from OCI to revenues in the consolidated statements of income (loss) ( 2017 : $ 23 million gains and 2016 : $ 48 million gains ). Based on market prices as of December 31, 2018 , unrealized losses of $ 14 million ( 2017 : $ 9 million losses and 2016 : $ 6 million gains ) recorded in accumulated other comprehensive income (“A OCI”) on energy derivative contracts are expected to be settled or reclassified into income in the next twelve months. The actual amount reclassified from AOCI, however, could vary due to future changes in market prices. The following table summarizes the energy derivative contracts designated as hedging instruments: Dec 31 Energy derivative contracts 2018 Carrying amount (asset/(liability)) (15) Notional amount - millions of U.S. dollars 188 Notional amount - GWh 5,024 Weighted average hedged rate for the year ($/MWh) 37 Maturity dates Jan 2019 - Dec 2020 Hedge ratio 1:1 Change in discounted spot value of outstanding hedging instruments (8) Change in value of hedged item used to determine hedge effectiveness 9 The hedge ineffectiveness loss recognized in Unrealized financial instruments loss in the consolidated statements of income related to energy derivative contracts (cash flow hedges) for the year ended December 31, 2018 was $ 2 million. (c) Interest rate hedges Brookfield Renewable has entered into interest rate hedge contracts primarily to minimize exposure to interest rate fluctuations on its variable rate debt or to lock in interest rates on future debt refinancing. All interest rate hedge contracts are recorded in the consolidated financial statements at fair value. There is an economic relationship between the hedged items and the hedging instruments as the terms of the interest rate hedges match the terms of the respective fixe d rate loans (i.e., notional amount, maturity, payment and reset dates). Brookfield Renewable established a hedge ratio of 1:1 for the hedging relationships as the underlying risk of the interest rate swaps are identical to the hedged risks. To test the he dge effectiveness, Brookfield Renewable uses the hypothetical derivative method and compares the changes in the fair value of the hedging instrument against the changes in fair value of the hedged items attributable to the hedged risk. The hedge ineffectiv eness can arise from: Different interest rate curves being applied to discount the hedged item and hedging instrument Differences in timing of cash flows of the hedged item and hedging instrument The counterparties’ credit risk having an asymmetrical impac t on the fair value movements of the hedging instrument and hedged item At December 31, 2018 , agreements with a total notional exposure of $ 1,444 million were outstanding ( 2017 : $ 1,704 million) including $ 383 million ( 2017 : $ 780 million) associated with agreements that are not formally designated as hedging instruments. The weighted-average fixed interest rate resulting from these agreements is 3.6 % ( 2017 : 4.5 % and 2016: 2.5%). For the year ended December 31, 2018 , net m ovements relating to cash flow hedges realized and reclassified from OCI to interest expense – borrowings in the consolidated statements of income (loss) were $ 14 million losses ( 2017 : $ 20 million and 2016 : $ 16 million). Based on market prices as of December 31, 2018 , unrealized losses of $ 10 million ( 2017 : $ 18 million and 2016 : $ 110 million) recorded in AOCI on interest rate swaps are expected to be settled or reclassified into income in the next twelve months. The actual amount recl assified from AOCI, however, could vary due to future changes in market rates. The following table summarizes the interest rate hedges designated as hedging instruments: Dec 31 Interest rate hedges 2018 Carrying amount (asset/(liability)) (25) Notional amount - $ 178 Notional amount - C$ (1) 151 Notional amount - € (1) 377 Notional amount - £ (1) 99 Notional amount - COP (1) 256 Maturity dates Aug 2019 - Sep 2036 Hedge ratio 1:1 Change in discounted spot value of outstanding hedging instruments 8 Change in value of hedged item used to determine hedge effectiveness (2) Notional amounts of foreign currency denominated interest rate hedges are presented at the U.S. dollar equivalent value based on the December 31, 2018 foreign currency spot rate The hedge ineffectiveness gain recognized in Unrealized financial instruments loss in the consolidated statements of income related to interest rate contracts (cash flow hedges) for the year ended December 31, 2018 was $ 9 million. (d ) Foreign exchange swaps Brookfield Renewable has entered into foreign exchange swaps to minimize its exposure to currency fluctuations impacting its investments and earnings in foreign operations, and to fix the exchange rate on certain anticipated transactions denominated in foreign currencies. There is an economic relationship between the hedged item and the hedging instrument as the net investment or anticipated foreign currency transaction creates a translation risk that will match t he respective hedging instrument. Brookfield Renewable established a hedge ratio of 1:1 as the underlying risk of the hedging instrument is identical to the hedged risk component. At December 31, 2018 , agreements with a total notional exposure of $ 1,844 million were outstanding ( 2017 : $ 2,306 million) including $ 957 million ( 2017 : $ 718 million) associated with agreements that are not formally designated as hedging instruments. There are no unrealized gains or losses record ed in AOCI on foreign exchange swaps that are expected to be settled or reclassified into income in the next twelve months ( 2017 : $ 48 million losses and 2016 : $ 1 million losses). The actual amount reclassified from AOCI, however, could vary due to future changes in market rates. The following table summarizes the foreign exchange swaps designated as hedging instruments: Dec 31 Foreign exchange swaps 2018 Carrying amount (asset/(liability)) 23 Notional amount for hedges of the Canadian dollar (1) 419 Notional amount for hedges of the Euro (1) 221 Notional amount for hedges of the British pounds sterling (1) 247 Maturity date Jan 2019 - Dec 2019 Hedge ratio 1:1 Weighted average hedged rate for the year: C$/$ foreign exchange forward contracts 1.34 €/$ foreign exchange forward contracts 0.82 £/$ foreign exchange forward contracts 0.76 Notional amounts expressed in millions of U.S. dollars The following table presents a reconciliation of the LP unitholder equity reserves impacted by financial instruments: Investments Foreign Cash flow in equity currency (MILLIONS) hedges securities translation Balance, as at December 31, 2017 $ (29) $ 15 $ (378) Effective portion of changes in fair value arising from: Energy derivative contracts (1) - - Interest rate swaps 1 - - Foreign exchange swaps - - 42 Amount reclassified to profit or loss 7 - - Foreign currency revaluation of designated borrowings - - 87 Foreign currency revaluation of net foreign operations - - (324) Valuation of investments in equity securities designated FVOCI - (8) - Tax effect (2) - (10) Other (10) (3) (69) Balance, as at December 31, 2018 $ (34) $ 4 $ (652)

SEGMENTED INFORMATION

SEGMENTED INFORMATION	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
SEGMENTED INFORMATION	6 . SEGMENTED INFORMATION Brookfield Renewable’s Chief Executive Officer and Chief Financial Officer (collectively, the chief operating decision maker or “CODM”) review the results of the business, manage operations, and allocate resources based on the type of technology. Our o per ations are segmented by – 1) hydroelectric, 2) wind, 3) solar, 4) storage & other ( co gen eration and biomass), and 5) corporate – with hydroelectric and wind further segmented by geography (i.e., North America, Colombia, Brazil, Europe and Asia). Our invest ment in the TerraForm Power and TerraForm Global businesses led to the creation of the solar segment which is now reviewed on a standalone basis. Our investment in First Hydro also resulted in the creation of a storage segment which is now reviewed along w ith our cogeneration and biomass businesses, on an aggregate basis. The Colombia segment aggregates the financial results of its hydroelectric and cogeneration facilities. The results of our wind assets in South Africa that are classified as held for sale have been aggregated in the Asia wind business segment. The corporate segment represents all activity performed above the individual segments for the business. Reporting to the CODM on the measures utilized to assess performance and allocate resources has been on a proportionate basis since the fourth quarter of 2017. Information on a proportionate basis reflects Brookfield Renewable’s share from facilities which it account s for using consolidation and the equity method whereby Brookfield Renewable either c ontrol s or exercise s significant influence or joint control over the investment, respectively. Proportionate information provides a Unitholder (h olders of the GP interest, Redeemable/Exchangeable partnership units, and LP Units ) perspective that the CODM considers important when performing internal analyses and making strategic and operating decisions. The CODM also believes that providing proportionate information helps investors understand the impacts of decisions made by management and financial result s allocable to Brookfield Renewable’s Unitholders. Proportionate financial information is not, and is not intended to be, presented in accordance with IFRS. Tables reconciling IFRS data with data presented on a proportionate consolidation basis have been d isclosed. Segment revenues, other income, direct operating costs, interest expense, depreciation, current and deferred income taxes, and other are items that will differ from results presented in accordance with IFRS as these items include Brookfield Renew able’s proportionate share of earnings from equity-accounted investments attributable to each of the above-noted items, and exclude the proportionate share of earnings (loss) of consolidated investments not held by us apportioned to each of the above-noted items. Brookfield Renewable do es not control those entities that have not been consolidated and as such, have been presented as equity-acc ounted investments in its financial statements. The presentation of the assets and liabilities and revenues and expenses do es not represent Brookfield Renewable’s legal claim to such items, and the removal of financial statement amounts that are attributab le to non-controlling interests does not extinguish Brookfield Renewable’s legal claims or exposures to such items. Brookfield Renewable report s its results in accordance with these segments and present s prior period segmented information in a consistent m anner. In accordance with IFRS 8, Operating Segments, Brookfield Renewable discloses information about its reportable segments based upon the measures used by the CODM in assessing performance. Except as it relates to proportionate financial information di scussed above, the accounting policies of the reportable segments are the same as those described in Note 1 – Basis of preparation and significant accounting policies. Brookfield Renewable analyzes the performance of its operating segments based on revenue s, Adjusted EBITDA, and Funds From Operations. Brookfield Renewable uses Adjusted EBITDA to assess the performance of its operations before the effects of interest expense, income taxes, depreciation, management service costs, non-controlling interests, unrealized gain or loss on financial instruments, non-cash gain or loss from equity-accounted investments, distributions to preferred shareholders and preferred limited partners and other typical non-recurring items. Brookfield Renewable uses Funds From Operations to assess the performance of its operations and is defined as Adjusted EBITDA less management service costs, interest and current income taxes , which is then adjusted for the cash portion of non-controlling interests an d distributions to preferred shareholders and preferred limited partners. The following table provides each segment’s results in the format that management organizes its segments to make operating decisions and assess performance and reconciles Brookfield Renewable’s proportionate results to the consolidated statements of income on a line by line basis by aggregating the components comprising the earnings from Brookfield Renewable’s investments in associates and reflecting the portion of each line item attributable to non-controlling interests for the year ended December 31 , 2018 : Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Solar Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Brazil Colombia America Europe Brazil Asia Other investments interests financials (1) Revenues 893 244 216 219 73 42 12 146 85 - 1,930 (286) 1,338 2,982 Other income 12 5 4 2 11 - - 5 - 7 46 (7) 11 50 Direct operating costs (286) (76) (94) (64) (27) (9) (4) (34) (36) (23) (653) 86 (469) (1,036) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - - - 207 20 227 Adjusted EBITDA 619 173 126 157 57 33 8 117 49 (16) 1,323 - 900 - Management service costs - - - - - - - - - (80) (80) - - (80) Interest expense - borrowings (172) (22) (38) (63) (17) (9) (4) (45) (17) (99) (486) 82 (301) (705) Current income taxes (4) (9) (2) (1) (2) - 1 - - - (17) 3 (16) (30) Distributions attributable to Preferred limited partners equity - - - - - - - - - (38) (38) - - (38) Preferred equity - - - - - - - - - (26) (26) - - (26) Share of interest and cash taxes from equity accounted investments - - - - - - - - - - - (85) (12) (97) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - - - (571) (571) Funds From Operations 443 142 86 93 38 24 5 72 32 (259) 676 - - - Depreciation (231) (136) (18) (122) (43) (13) (2) (40) (23) (2) (630) 96 (285) (819) Foreign exchange and unrealized financial instrument loss (1) (1) 7 2 9 (10) 3 (9) (2) - (2) (3) (29) (34) Deferred income tax recovery (1) 1 18 20 2 - - 21 - 24 85 (50) 54 89 Other (21) (3) (6) (11) (1) - (2) (11) (9) (23) (87) 19 (14) (82) Share of earnings from equity accounted investments - - - - - - - - - - - (62) - (62) Net income attributable to non-controlling interests - - - - - - - - - - - - 274 274 Net income (loss) attributable to Unitholders (2) 189 3 87 (18) 5 1 4 33 (2) (260) 42 - - 42 Share of earnings from equity-accounted investments of $68 million is comprised of amounts found on the share of Adjusted EBITDA, share of interest and cash taxes and share of earnings lines. Net income attributable to participating non-contr olling interests – in operating subsidiaries of $ 297 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests. Net income (loss) attribu table to Unitholders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limited partners equity and preferred equity. The following table provides each segment’s results in the format that management organizes its segments to make operating decisions and assess performance and reconciles Brookfield Renewable’s proportionate results to the consolidated statements of income on a line by line basis by aggregating the components comprising the earnings from Brookfield Renewable’s investments in associates and reflecting the portion of each line item attributable to non-controlling interests for the year ended December 31 , 2017 : Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Solar Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Brazil Colombia America Europe Brazil Other investments interests financials (1) Revenues 945 243 191 161 46 26 8 59 - 1,679 (74) 1,020 2,625 Other income 1 12 2 - - - - 6 19 40 (11) 18 47 Direct operating costs (281) (77) (94) (42) (20) (4) (2) (32) (25) (577) 28 (429) (978) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 57 - 57 Adjusted EBITDA 665 178 99 119 26 22 6 33 (6) 1,142 - 609 - Management service costs - - - - - - - - (82) (82) - - (82) Interest expense - borrowings (180) (18) (42) (45) (10) (6) (3) (14) (89) (407) 21 (246) (632) Current income taxes 1 (12) (5) - (1) - (1) - - (18) 1 (22) (39) Distributions attributable to Preferred limited partners equity - - - - - - - - (28) (28) - - (28) Preferred equity - - - - - - - - (26) (26) - - (26) Share of interest and cash taxes from equity accounted investments - - - - - - - - - (22) - (22) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - (341) (341) Funds From Operations 486 148 52 74 15 16 2 19 (231) 581 - - - Depreciation (220) (142) (26) (90) (25) (7) (4) (25) - (539) 22 (265) (782) Foreign exchange and unrealized financial instrument loss (12) (3) (3) 1 (14) - (1) - (15) (47) 2 (1) (46) Deferred income tax expense (67) 2 (10) 28 5 - 1 - 16 (25) (3) (21) (49) Other (17) (8) 6 (4) 4 2 (3) - (6) (26) 12 (1) (15) Share of earnings from equity accounted investments - - - - - - - - - - (33) - (33) Net income attributable to non-controlling interests - - - - - - - - - - - 288 288 Net income (loss) attributable to Unitholders (2) 170 (3) 19 9 (15) 11 (5) (6) (236) (56) - - (56) Share of earnings from equity-accounted investments of $2 million is comprised of amounts found on the share of Adjusted EBITDA, share of interest and cash taxes and share of earnings lines. Net income attributable to participating non-controlling interests – in operating subsidiaries of $ 53 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests. Net income (los s) attributable to Unitholders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limite d partners equity and preferred equity. The following table provides each segment’s results in the format that management organizes its segments to make operating decisions and assess performance and reconciles Brookfield Renewable’s proportionate results to our consolidated statements of income on a line by line basis by aggregating the components comprising the earnings from Brookfield Renewable ’s investments in associates and reflecting the portion of each line item attributable to non-controlling interests for the year ended December 31 , 2016 : Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Brazil Colombia America Europe Brazil Other investments interests financials (1) Revenues 819 187 192 151 56 17 58 1 1,481 (37) 1,008 2,452 Other income 24 13 3 - - - (1) 8 47 - 17 64 Direct operating costs (295) (70) (107) (36) (24) (4) (26) (24) (586) 16 (468) (1,038) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 21 - 21 Adjusted EBITDA 548 130 88 115 32 13 31 (15) 942 - 557 - Management service costs - - - - - - - (62) (62) - - (62) Interest expense - borrowings (177) (24) (36) (41) (14) (7) (12) (91) (402) 12 (216) (606) Current income taxes (4) (9) (6) - - - - - (19) - (25) (44) Distributions attributable to Preferred limited partners equity - - - - - - - (15) (15) - - (15) Preferred equity - - - - - - - (25) (25) - - (25) Share of interest and cash taxes from equity accounted investments - - - - - - - - - (12) - (12) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - (316) (316) Funds From Operations 367 97 46 74 18 6 19 (208) 419 - - - Depreciation (244) (125) (31) (80) (38) (4) (18) - (540) 11 (252) (781) Foreign exchange and unrealized financial instrument loss 1 - 1 - - - 2 - 4 - - 4 Deferred income tax expense (recovery) 31 7 6 49 6 - - (21) 78 - 19 97 Other (27) (5) 3 4 6 (1) (2) (4) (26) (2) (18) (46) Share of earnings from equity accounted investments - - - - - - - - - (9) - (9) Net income attributable to non-controlling interests - - - - - - - - - - 251 251 Net income (loss) attributable to Unitholders (2) 128 (26) 25 47 (8) 1 1 (233) (65) - - (65) Share of earnings from equity-accounted investments of $nil is comprised of amounts found on the share of Adjusted EBITDA, share of interest and cash taxes and share of earnings lines. Net income attributable to participating non-controlling interests – in operating subsidiaries of $ 65 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests. Net income (loss) attributable to Unith olders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limited partners equity and pr eferred equity. The following table presents information on a segmented basis about certain items in Brookfield Renewable’s statement of financial position: Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Solar Storage Corporate Total equity to non- As per North North and accounted controlling IFRS (MILLIONS) America Colombia Brazil America Europe Brazil Asia Other investments interests financials As at December 31, 2018: Cash and cash equivalents $ 6 $ 7 $ 37 $ 30 $ 29 $ 5 $ 2 $ 41 $ 9 $ 3 $ 169 $ (81) $ 85 $ 173 Property, plant and equipment, at fair value 11,498 1,609 1,907 2,480 819 348 36 1,354 686 (9) 20,728 (3,529) 11,826 29,025 Total assets 12,125 1,868 2,105 2,554 939 379 56 1,650 746 161 22,583 (2,483) 14,003 34,103 Total borrowings 2,995 419 198 1,204 463 75 31 1,021 249 2,334 8,989 (1,972) 3,701 10,718 Other liabilities 2,764 434 150 536 124 7 3 255 31 211 4,515 (511) 2,175 6,179 For the year ended December 31, 2018: Additions to property, plant and equipment 96 7 30 11 10 - - 9 3 6 172 (16) 145 301 As at December 31, 2017: Cash and cash equivalents $ 21 $ 14 $ 40 $ 18 $ 19 $ 7 $ 103 $ 90 $ 11 $ 7 330 $ (30) $ 499 $ 799 Property, plant and equipment, at fair value 11,396 1,303 1,908 1,798 482 304 11 602 625 - 18,429 (1,451) 10,118 27,096 Total assets 11,709 1,574 2,149 1,888 532 443 31 765 691 180 19,962 (1,040) 11,982 30,904 Total borrowings 3,049 447 200 1,005 233 192 9 499 253 2,552 8,439 (848) 4,175 11,766 Other liabilities 2,188 354 180 333 101 16 9 74 51 234 3,540 (191) 1,507 4,856 For the year ended December 31, 2017: Additions to property, plant and equipment 90 8 59 6 34 - - - 13 10 220 (10) 144 354 Geographical Information The following table presents consolidated revenue spli t by geographical region for the year ended December 31 : (MILLIONS) 2018 2017 2016 United States $ 926 $ 871 $ 786 Colombia 896 797 819 Canada 428 480 442 Brazil 429 366 269 Europe 126 111 136 Asia 177 - - $ 2,982 $ 2,625 $ 2,452 The following table presents consolidated property, plant and equipment and equity-accounted investments split by geographical region: Dec 31 Dec 31 (MILLIONS) 2018 2017 United States $ 12,705 $ 11,131 Colombia 6,665 5,401 Canada 5,705 5,810 Brazil 3,553 3,479 Europe 1,624 1,332 Asia 342 664 $ 30,594 $ 27,817

OTHER INCOME

OTHER INCOME	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
Other income	7 . OTHER INCOME Brookfield Renewable’s other income for the year ended December 31 is comprised of the following : (MILLIONS) Notes 2018 2017 2016 Interest income and other $ 22 $ 32 $ 41 Gain on available for sale investments - 15 - Gains on settlement of foreign currency contracts 28 - 23 $ 50 $ 47 $ 64

DIRECT OPERATING COSTS

DIRECT OPERATING COSTS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
DIRECT OPERATING COSTS	8 . DIRECT OPERATING COSTS Brookfield Renewable’s direct operating costs for the year ended December 31 are comprised of the following: (MILLIONS) Notes 2018 2017 2016 Operations, maintenance and administration $ 581 $ 567 $ 553 Water royalties, property taxes and other 142 161 149 Fuel and power purchases (1) 289 226 313 Energy marketing fees 27 24 24 23 $ 1,036 $ 978 $ 1,038 F uel and power purchase s are primarily attributable to our portfolio in Colombia.

OTHER

OTHER	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
Other	9 . O THER Brookfield Renewable’s other for the year ended December 31 is comprised of the following : (MILLIONS) 2018 2017 2016 Transaction costs $ 2 $ 9 $ 22 Change in fair value of property, plant and equipment 44 33 36 Other 36 (27) (12) $ 82 $ 15 $ 46

FOREIGN CURRENCY TRANSLATION

FOREIGN CURRENCY TRANSLATION	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
FOREIGN CURRENCY TRANSLATION	10 . FOREIGN CURRENCY TRANSLATION Brookfield Renewable’s foreign currency translation for the year ended December 31 shown in the consolidated statements of comprehensive income is comprised of the following : (MILLIONS) Notes 2018 2017 2016 Foreign currency translation on Property, plant and equipment, at fair value 12 $ (1,512) $ 506 $ 1,186 Borrowings 13 537 (282) (244) Deferred income tax liabilities and assets 11 184 (82) (157) Other assets and liabilities (34) 48 201 $ (825) $ 190 $ 986

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
INCOME TAXES	11 . Income taxes The major components of income tax recovery (expense) for the year ended December 31 are as follows: (MILLIONS) 2018 2017 2016 Income tax recovery (expense) applicable to: Current taxes Attributed to the current period $ (30) $ (39) $ (44) Deferred taxes Income taxes - origination and reversal of temporary differences $ 2 $ 8 $ 71 Relating to change in tax rates / imposition of new tax laws 95 (42) 35 Relating to unrecognized temporary differences and tax losses (8) (15) (9) $ 89 $ (49) $ 97 Total income tax recovery (expense) $ 59 $ (88) $ 53 The major components of deferred income tax recovery (expense) for the year ended December 31 recorded directly to OCI are as follows: (MILLIONS) 2018 2017 2016 Deferred income taxes attributed to: Financial instruments designated as cash flow hedges $ (2) $ (4) $ 2 Other (20) 15 (7) Revaluation surplus Origination and reversal of temporary differences (1,117) (248) (55) Relating to changes in tax rates / imposition of new tax laws 54 586 19 $ (1,085) $ 349 $ (41) Brookfield Renewable’s effective income tax (expense) recovery for the year ended December 31 is different from its recovery at its statutory income tax rate due to the differences below: (MILLIONS) 2018 2017 2016 Statutory income tax (expense) recovery (1) $ (100) $ (50) $ 5 Reduction (increase) resulting from: Increase in tax assets not recognized (8) (15) (9) Differences between statutory rate and future tax rate 95 (37) 43 Subsidiaries' income taxed at different rates 75 14 14 Other (3) - - Effective income tax recovery (expense) $ 59 $ (88) $ 53 Statutory income tax expense is calculated at the domestic rates applicable to the profits in the country concerned. The above reconciliation has been prepared by aggregating the information for all of Brookfield Renewable’s subsidiaries using the domestic rate in each tax jurisdiction. Brookfield Renewable’s effective income tax rate was (17.15) % for the year ended December 31, 2018 ( 2017 : 63.31 % and 2016: 384.03%). The effective tax rate is less than the statutory rate primaril y due to rate differentials, legislative changes in tax rates during the year, and non-controlling interests’ income not subject to tax. The following table details the expiry date, if applicable, of the unrecognized deferred tax assets as at December 31: (MILLIONS) 2018 2017 2016 2019 to 2023 $ 3 $ 8 $ - 2024 and thereafter 85 108 98 $ 88 $ 116 $ 98 The deferred tax assets and liabilities of the following temporary differences have been recognized in the consolidated financial statements for the year ended December 31: Difference Net deferred Non-capital between tax and tax (liabilities) (MILLIONS) losses carrying value assets As at January 1, 2016 $ 458 $ (2,996) $ (2,538) Recognized in Net income (loss) 24 73 97 Recognized in equity 17 (48) (31) Business combination - (1,020) (1,020) Foreign exchange - (160) (160) As at December 31, 2016 499 (4,151) (3,652) Recognized in Net income (loss) (97) 48 (49) Recognized in equity 13 341 354 Business combination 79 (63) 16 Foreign exchange 14 (94) (80) As at December 31, 2017 508 (3,919) (3,411) Recognized in Net income (loss) (60) 149 89 Recognized in equity 1 (985) (984) Business combination - 73 73 Foreign exchange (20) 204 184 As at December 31, 2018 $ 429 $ (4,478) $ (4,049) The deferred income tax liabilities include $ 3,685 million ( 2017 : $ 2,561 million and 2016: $2,948 million) of liabilities which relate to property, plant and equipment revaluations included in equity. The taxable temporary difference attributable to Brookfield Renewable’s interest in its subsidiaries, branches, associates, and joint ventures is $ 3,398 million ( 2017 : $ 1,549 million and 2016: $1,380 million ). No deferred income tax liability has been recognized in the financial statements in respect of this taxable temporary difference .

PROPERTY, PLANT AND EQUIPMENT,

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE	12 . PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE The following table presents a reconciliation of property, plant and equipment at fair value : (MILLIONS) Notes Hydro Wind Solar Other (1) Total (2) As at December 31, 2015 $ 14,847 $ 3,233 - $ 278 $ 18,358 Additions 269 71 - 18 358 Acquisitions through business combinations 3 5,731 10 - - 5,741 Items recognized through OCI Change in fair value 190 187 - 54 431 Foreign exchange 1,114 21 - 51 1,186 Items recognized through net income Change in fair value (17) (10) - (9) (36) Depreciation (565) (199) - (17) (781) As at December 31, 2016 $ 21,569 $ 3,313 - $ 375 $ 25,257 Additions 253 95 - 6 354 Acquisitions through business combinations 3 - 670 575 - 1,245 Disposal - (338) - - (338) Items recognized through OCI Change in fair value 828 91 - (32) 887 Foreign exchange 332 177 - (3) 506 Items recognized through net income Change in fair value (20) (8) - (5) (33) Depreciation (563) (197) - (22) (782) As at December 31, 2017 $ 22,399 $ 3,803 $ 575 $ 319 $ 27,096 Additions 212 36 47 6 301 Acquisitions through business combinations 3 - 125 86 - 211 Transfer to assets held for sale 4 - (58) (691) - (749) Items recognized through OCI Change in fair value 3,775 466 313 4 4,558 Foreign exchange (1,138) (256) (77) (41) (1,512) Items recognized through net income Change in fair value (33) (20) - (8) (61) Depreciation (536) (236) (25) (22) (819) As at December 31, 2018 $ 24,679 $ 3,860 $ 228 $ 258 $ 29,025 Includes biomass and cogeneration. Includes intangible assets of $ 11 million ( 2017 : $ 1 3 million and 2016: $14 million ) and assets under construction of $ 388 million (201 7 : $ 601 million and 2016: $ 663 million ). The fair value of Brookfield Renewable’s property, plant and equipment is calculated as described in Not es 1(h) – Property, plant and equipment and revaluation method and 1(q)(i) – Critical estimate s – property, plant and equipment . Judgment is involved in determining the appropriate estimates and assumptions in the valuation of Brookfield Renewable’s property, plant and equipment. See Note 1(r)(iii) - Critical judgments in applying accounting policies – Property, plant and equipment . Brookfield Renewable has classified its property, p lant and equipment under level 3 of the fair value hierarchy. Discount rates, terminal capitalization rates and exit dates used in the valuation methodology are provided in the following table North America Colombia Brazil Europe 2018 2017 2018 2017 2018 2017 2018 2017 Discount rate (1) Contracted 4.8% - 5.6% 4.9% - 6.0% 9.6% 11.3% 9.0% 8.9% 4.0% - 4.3% 4.1% - 4.5% Uncontracted 6.4% - 7.2% 6.5% - 7.6% 10.9% 12.6% 10.3% 10.2% 5.8% - 6.1% 5.9% - 6.3% Terminal capitalization rate (2) 6.1% - 7.1% 6.2% - 7.5% 10.4% 12.6% N/A N/A N/A N/A Exit date 2038 2037 2038 2037 2047 2032 2033 2031 Discount rates are not adjusted for asset specific risks. The terminal capitalization rate applies only to hydroelectric assets in the United States, Canada and Colombia. The following table summarizes the impact of a change in discount rates , electricity prices and terminal capitalization rates on the fair value of property, plant and equipment: 2018 North (MILLIONS) America Colombia Brazil Europe Total 25 bps increase in discount rates $ (770) $ (180) $ (80) $ (20) $ (1,050) 25 bps decrease in discount rates 840 190 80 20 1,130 5% increase in future electricity prices 800 370 100 20 1,290 5% decrease in future electricity prices (800) (370) (100) (20) (1,290) 25 bps increase in terminal capitalization rate (1) (210) (30) - - (240) 25 bps decrease in terminal capitalization rate (1) 230 30 - - 260 2017 North (MILLIONS) America Colombia Brazil Europe Total 25 bps increase in discount rates $ (710) $ (130) $ (50) $ (20) $ (910) 25 bps decrease in discount rates 770 130 50 20 970 5% increase in future electricity prices 620 310 70 20 1,020 5% decrease in future electricity prices (620) (310) (70) (20) (1,020) 25 bps increase in terminal capitalization rate (1) (180) (20) - - (200) 25 bps decrease in terminal capitalization rate (1) 190 20 - - 210 The terminal capitalization rate applies only to hydroelectric assets in the United States, Canada and Colombia . Terminal values are included in the valuation of hydroelectric assets in the United States, Canada and Colombia. For the hydroelectric assets in Brazil, cash flows have been included based on the duration of the authorization or useful life of a concession asset plus a one-time 30-year renewal term for the majority of our hydroelectric assets. In November 2016, the Brazilian federal government published a new law which allowed a one-time extension of authorization licenses of hydroelectric facilit ies with installed capacities in the range of 5 MW to 50 MW. Only after the Brazilian federal government clarified the technical and cost requirements associated with the authorization extension in June of 2018 did Brookfield Renewable include the one-tim e 30-year extension in the valuation of the relevant hydroelectric assets in Brazil. The weighted-average remaining duration of the authorization or useful life of a concession asset at December 31, 2018 , including a one-time 30-year renewal for a pplicable hydroel ectric assets , is 29 years ( 2017 : 15 years). Consequently, there is no terminal value attributed to the hydroelectric assets in Brazil at the end of the authorization term . The following table summarizes the percentage of total generation contracted under power purchase agreements as at December 31, 2018 : North America Colombia Brazil Europe 1 - 10 years 57% 22% 69% 72% 11 - 20 years 34% 0% 35% 25% The following table summarizes power prices from long-term power purchase agreements that are linked specifically to the related power generating assets: Per MWh (1) North America Colombia Brazil Europe 1 - 10 years $ 83 COP 201,000 R$ 286 € 93 11 - 20 years 80 - 397 111 Assumes nominal prices based on weighted-average generation. The following table summarizes the estimates of future electricity prices: Per MWh (1) North America Colombia Brazil Europe 1 - 10 years $ 68 COP 252,000 R$ 287 € 79 11 - 20 years 116 354,000 452 92 Assumes nominal prices based on weighted-average generation. Brookfield Renewable’s long-term view is anchored to the cost of securing new energy from renewable sources to meet future demand growth between 2022 and 2025. A further one year change would increase or decrease the fair value of property, plant and equipment by approximately $ 150 million ( 2017 : $ 160 million). Had Brookfield Renewable’s revalued property, plant and equipment been measured on a historical cost basis, the carrying amounts, net of accumulated depreciation would have been as follows at December 31: (MILLIONS) 2018 2017 Hydroelectric $ 11,888 $ 12,740 Wind 2,753 3,030 Solar 260 621 Other (1) 246 312 $ 15,147 $ 16,703 Includes biomass and co g eneration.

BORROWINGS

BORROWINGS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
LONG-TERM DEBT AND CREDIT FACILITIES	13 . BORROWINGS Corporate Borrowings The composition of corporate borrowings as at December 31 is p resented in the following table: 2018 2017 Weighted-average Estimated Weighted-average Estimated Interest Term Carrying fair Interest Term Carrying fair (MILLIONS EXCEPT AS NOTED) rate (%) (years) value value rate (%) (years) value value Credit facilities 3.3 4.4 $ 727 $ 727 2.6 4.5 $ 887 $ 887 Medium Term Notes: Series 3 (C$200) - - $ - $ - 5.3 0.8 $ 159 $ 163 Series 4 (C$150) 5.8 17.9 110 124 5.8 18.9 119 144 Series 7 (C$450) 5.1 1.8 330 342 5.1 2.8 358 382 Series 8 (C$400) 4.8 3.1 293 309 4.8 4.1 318 344 Series 9 (C$400) 3.8 6.4 293 288 3.8 7.4 318 321 Series 10 (C$500) 3.6 8.0 367 357 3.6 9.0 398 400 Series 11 (C$300) 4.3 10.0 220 220 - - - - 4.4 6.5 $ 1,613 $ 1,640 4.5 6.4 $ 1,670 $ 1,754 Total corporate borrowings 2,340 2,367 2,557 2,641 Less: Unamortized financing fees (1) (6) (5) Less: Current portion (6) (159) $ 2,328 $ 2,393 Unamortized premiums and unamortized financing fees are amortized over the terms of the borrowing. The following table outlines the change in the unamortized financing fees of corporate borrowings for the year ended December 31: (MILLIONS) 2018 2017 2016 Corporate borrowings Unamortized financing fees, beginning of year $ 5 $ 6 $ 5 Additional financing fees 2 - 2 Amortization of financing fees (1) (1) (1) Unamortized financing fees, end of year $ 6 $ 5 $ 6 Credit facilities In June 2018, Brookfield Renewable extended the maturity of $ 1.7 billion of its corporate credit facilities by one year to June 30, 2023. The credit facilities are used for general working capital purposes and issuing letters of credit. The credit facilities bear interest at the applicable rate plus an applicable margin. The applicable margin is tiered on the basis of Brookfield Renewable’s unsecured senior long-term debt rating and is currently 1.20 %. In May 2018, Brookfield Rene wable entered in to an agreement for a $ 300 million export credit agency guaranteed letter of credit facility. As at December 31, 2018, $ 201 million is utilized on the facility replacing the previous utilization on Brookfield Renewable’s revolving credit fa cility. In December 2018, Brookfield Renewable extended the maturity of the $ 400 million committed unsecured credit facility provided by Brookfield Asset Management by one year to December 2019 . The interest rate is LIBOR plus up to 2 %. Brookfield Renewab le repaid all outstanding draws and accrued interest from the $400 million unsecured revolving credit facility as of December 31, 2018. During the year, Brookfield Asset Management had also placed funds on deposit with Brookfield Renewable in the amount of $ 200 million, which have since been paid back in full including any interest that had been accrued. The interest expense on the deposit and draws from the credit facility for the year ended December 31, 2018 totaled $ 8 million (2017: $ 1 million). Subsequent to December 31, 2018, Brookfield Asset Management placed funds on deposit with Brookfiel d Renewable in the amount of $ 251 million. Brookfield Renewable issues letters of credit from its corporate credit facilities for general corporate purposes which include, but are not limited to, security deposits, performance bonds and guarantees for debt service reserve accounts. The following table summarizes the available portion of corporate credit facilities as at December 31: (MILLIONS) 2018 2017 Authorized corporate credit facilities (1) $ 2,100 $ 2,090 Draws on corporate credit facilities (1) (721) (685) Issued letters of credit (8) (193) Available portion of corporate credit facilities 1,371 1,212 Amounts are guaranteed by Brookfield Renewable. Excludes $ 6 million ( 2017 : $ 202 million) borrowed under a subscription facility of a Brookfield sponsored private fund. Medium term notes Corporate borrowings are obligations of a finance subsidiary of Brookfield Renewable, Brookfield Renewable Partners ULC (“ Finco ”) (Note 30 - Subsidiary Public Issuers). Finco may redeem some or all of the borrowings from time to time, pursuant to the terms of the indenture. The balance is payable upon maturity, and interest on corporate borrowings is paid semi-annually. The term notes payabl e by Finco are unconditionally guaranteed by Brookfield Renewable, Brookfield Renewable Energy L.P. (“BRELP”) and certain other subsidiaries. On September 20, 2018, Brookfield Renewable completed the issuance of C$ 300 million ($ 231 million) Series 11 mediu m-term notes which carry a fixed interest rate of 4.25 % and mature in January 2029 . The financing was Brookfield Renewable’s inaugural corporate-level green bond. In November 2018, Brookfield Renewable repaid C$ 200 million ($ 153 million) of medium-term not es upon maturity. Non-recourse borrowings Non-recourse borrowings are typically asset-specific, long-term, non-recourse borrowings denominated in the domestic currency of the subsidiary. Non-recourse borrowings in North America and Europe consist of both fixed and floating interest rate debt indexed to the Lo ndon Interbank Offered Rate (“LIBOR”) and the Canadian Dollar Offered Rate (“CDOR”) . Brookfield Renewable uses interest rate sw ap agreements in North America and Europe to minimize its exposure to floating interest rates. Non-recourse borrowings in Brazil consist of floating interest rates of Taxa de Juros de Longo Prazo (“TJLP”), the Brazil National Bank for Economic Development’s long-term interest rate, or Interbank Deposit Certificate rate (“CDI”), plus a margin. Non-recourse borrowings in Colombia incl ude floating interest rates of Indicador Bancario de Referencia rate (“IBR”), the Banco Central de Colombia short-term interest rate, or Colombian Consumer Price Index (“IPC”), the Banco Central de Colombia inflation r ate, plus a margin . Non-recourse borro wings in India consist of fixed interest rate U.S. dollar denominated debt. The composition of non-recourse borrowings as at December 31 is presented in the following table: 2018 2017 Weighted-average Estimated Weighted-average Estimated Interest Term Carrying fair Interest Term Carrying fair (MILLIONS EXCEPT AS NOTED) rate (%) (years) value value rate (%) (years) value value Non-recourse borrowings Hydroelectric 6.1 9.2 $ 6,318 $ 6,517 6.3 8.8 $ 6,392 $ 6,813 Wind 4.7 10.8 1,908 1,951 5.8 9.7 2,211 2,343 Solar 6.0 7.1 142 133 11.1 7.6 643 643 Storage and other 4.0 4.9 91 95 8.4 17.8 39 39 Total 5.7 9.5 $ 8,459 $ 8,696 6.5 9.0 $ 9,285 $ 9,838 Add: Unamortized premiums (1) 1 1 Less: Unamortized financing fees (1) (76) (72) Less: Current portion (489) (1,517) $ 7,895 $ 7,697 Unamortized premiums and unamortized financing fees are amortized over the terms of the borrowing. Future repayments of Brookfield Renewable’s non-recourse borrowings for each of the next five years and thereafter are as follows: (MILLIONS) 2019 2020 2021 2022 2023 Thereafter Total Non-recourse borrowings Hydro 306 446 164 491 1,084 3,827 6,318 Wind 169 119 129 128 161 1,202 1,908 Solar 13 - 4 - - 125 142 Storage and other 1 1 77 1 1 10 91 $ 489 $ 566 $ 374 $ 620 $ 1,246 $ 5,164 $ 8,459 The following table outlines the change in the unamortized financing fees of non-recourse borrowings for the year ended December 31: (MILLIONS) 2018 2017 2016 Non-recourse borrowings Unamortized financing fees, beginning of year $ 72 $ 74 $ 54 Additional financing fees 21 16 41 Amortization of financing fees (12) (14) (17) Foreign exchange translation and other (5) (4) (4) Unamortized financing fees, end of year $ 76 $ 72 $ 74 On January 19, 2018, Brookfield Renewable completed financing associate d with its equity-accounted 2.1 GW pumped storage facility in the United Kingdom by securing £ 60 million ($ 83 million) of non-recourse borrowings and £ 90 million ($ 125 mill ion) letter of credit facility. The non-recourse borrowings mature in 2021 and bear interest at LIBOR plus a margin of 2.75 %. On January 29, 2018, Brookfield Renewable completed R$ 130 million ($ 40 million) of financing with respect to a 19 MW hydroelectric facility currently under construction in Bra zil. The loan bears interest at a rate of TJLP plus 2.15 % and matures in 2038 . On February 15, 2018, Brookfield Renewable completed a refin ancing associated with a 296 MW hydroelectric facility in the United Sta tes. The financing was a $ 350 m illion interest only green bond bearing interest at 4.5 %, maturing in 2033 . Proceeds were used to repay t he existing principal amount of $315 million and the excess was distributed to investors. On February 22, 2018, TerraFor m Global issued $ 400 million of senior no tes at 6.13 %, maturing in March 2026 . Along with cash on the balance sheet, proceeds were used to rep ay the existing $ 760 million of 9.75 % senior notes due in 2022 . Additionally, TerraForm Global secured a $ 45 milli on revolving credit facility, maturing in February 2021 . On February 27, 2018, Brookfield Renewable completed bond financing associated with the Colombian business . The financing was a COP 750 billion ($ 262 million) in senior unsecured bonds with maturitie s of 7 , 12 and 30 years at rates of 7.12 %, IPC + 3.56 % and IPC + 3.99 %, respectively . On April 20, 2018, Brookfield Renewable completed a R$ 160 million ($ 47 million) refinancing associated with a 120 MW hydroelectric facility in Brazil. The loan bears an i nterest rate of CDI + 2.00 %, maturing in October 2023 . In the second quarter of 2018, Brookfield Renewable completed a refinancing of COP 1,762 billion ($ 634 million) of bank debt associated with the Colombian business. The new loans mature between 2025 an d 2030 years at rates ranging of IBR + 2.97 % to IBR + 3.70 %. On August 31, 2018, Brookfield Renewable completed a refinancing of COP 338 billion ($ 111 million) of debt associated with the Colombian business. The amortizing loan bears a fixed interest rate of 7.48 % and matures in August 2025 . On September 14, 2018, Brookfield Renewable completed a R$ 250 million ($ 60 million) financing associated with the Brazilian hydroelectric business. The debenture bears interest at 113 % of CDI and matures in September 20 23 . On September 28, 2018, Brookfield Renewable increased indebtedness associated with a 166 MW wind portfolio in Ontario through a C$ 60 million ($ 46 million) private placement. The debt bears a fixed rate of 4.86 % and matures in August 2031 . On October 2 6 , 2018, Brookfield Renewable completed a £ 29 million ($ 37 million) financing associated with the acquisition of a 23 MW Northern Ir eland wind facility. The debt matures in September 2036 and bears interest at GBP LIBOR plus a margin of 1.85 %. On November 2 6, 2018, Brookfield Renewable completed a commercial paper issuance of COP 250 billion ($ 77 million) associated with the Colombian business. The issuance bears interest at IBR + 0.70 % and has a term of 330 days . On December 11, 2018, Brookfield Renewable e xtended the maturity of COP 593 billion ($ 186 million) of local bank debt and $ 196 million of bank debt associated with the Colombian business by 2 years to January 2023 . The COP tranche bears interest at IBR + 3.50 % and the USD tranche bears interest at L IBOR + 2.50 %. On December 12, 2018, Brookfield Renewable completed a $ 190 million refinancing associated with a 377 MW hydroelectric portfolio in the United States. The loan bears interest at LIBOR plus a margin of 3.00 % and matures in December 2022 . On De cember 20, 2018, Brookfield Renewable completed a C$ 150 million ($ 111 million) financing associated with a 488 MW hydroelectric portfolio in Canada. The loan bears interest at CDOR plus a margin of 1.40 % and matures in November 2020 . On December 20, 2018, Brookfield Renewable completed a C$ 160 million ($ 119 million) financing associated with a 351 MW hydroelectric portfolio in Canada. The loan bears interest at CDOR plus a margin of 1.60 % and matures in June 2023 . Supplemental Information The following table outlines changes in Brookfield Renewable’s borrowings for the year ended December 31: Net cash flows from Non-cash (MILLIONS) Jan 1 financing activities Acquisition Held for sale Disposal Other (1) Dec 31 2018 Corporate borrowings $ 2,552 (88) - - - (130) $ 2,334 Non-recourse borrowings $ 9,214 (178) 90 (360) - (382) $ 8,384 2017 Corporate borrowings $ 2,229 191 - - - 132 $ 2,552 Non-recourse borrowings $ 7,953 76 1,188 - (173) 170 $ 9,214 Includes foreign exchange and amortization of unamortized premium and financing fees.

NON-CONTROLLING INTERESTS

NON-CONTROLLING INTERESTS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
NON-CONTROLLING INTERESTS	14 . NON-CONTROLLING INTERESTS Brookfield Renewable’s non-controlling interests are comprised of the following as at December 31: (MILLIONS) 2018 2017 Participating non-controlling interests - in operating subsidiaries $ 8,129 $ 6,298 General partnership interest in a holding subsidiary held by Brookfield 66 58 Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield 3,252 2,843 Preferred equity 568 616 $ 12,015 $ 9,815 Participating non-controlling interests – in operating subsidiaries The net change in participating non-controlling interests – in operating subsidiaries is as follows: Brookfield Isagen Isagen public Americas Brookfield Brookfield Canadian The institu- non-con Infrastructure Infrastructure Infrastructure Hydroelectric Catalyst tional -trolling (MILLIONS) Fund Fund II Fund III Portfolio Group investors interests Other Total As at December 31, 2015 $ 958 $ 1,441 $ - $ - $ 121 $ - $ - $ 67 $ 2,587 Net income (18) (16) 15 - 16 47 19 2 65 OCI 46 228 - - 2 148 205 6 635 Capital contributions - 74 1,074 - - 1,473 - - 2,621 Acquisition - - - - - - 1,417 - 1,417 Distributions (23) (73) (7) - (12) - - (4) (119) MTO adjustments - - 3 - - 7 (1,627) - (1,617) As at December 31, 2016 $ 963 $ 1,654 $ 1,085 $ - $ 127 $ 1,675 $ 14 $ 71 $ 5,589 Net (loss) income (29) (13) 33 - 12 47 - 3 53 OCI (76) 269 111 - 2 78 (1) - 383 Capital contributions - 89 186 - - 19 - - 294 Acquisition - - 525 - - - - - 525 Distributions (8) (317) (88) - (7) (115) - (4) (539) Purchase of Isagen shares - - (1) - - (5) 5 - (1) Other - - 1 - - 2 (9) - (6) As at December 31, 2017 $ 850 $ 1,682 $ 1,852 $ - $ 134 $ 1,701 $ 9 $ 70 $ 6,298 Net income 1 9 86 4 14 174 1 8 297 OCI 66 298 805 (11) (18) 504 5 58 1,707 Capital contributions - 9 5 293 - - - - 307 Acquisition - - - - - - - 21 21 Distributions (17) (81) (276) - (6) (167) - (6) (553) Other - 12 (3) (10) - - - 53 52 As at December 31, 2018 $ 900 $ 1,929 $ 2,469 $ 276 $ 124 $ 2,212 $ 15 $ 204 $ 8,129 Interests held by third parties 75-80% 43-60% 23-71% 25-44% 25% 53% 0.5% 20-50% - The following tables summarize certain financial information of operating subsidiaries that have non-controlling interests that are material to Brookfield Renewable: Brookfield Americas Brookfield Brookfield Canadian The Infrastructure Infrastructure Infrastructure Hydroelectric Catalyst (MILLIONS) Fund Fund II Fund III (1) Portfolio Group Isagen (2) Other Total Interests held by third parties 75-80% 43-60% 69-71% 25-44% 25% 76% 20-50% Place of business United States, Brazil United States, Brazil, Europe United States, Brazil, India, China Canada United States Colombia United States, Brazil, Canada Year ended December 31, 2016: Revenue $ 118 $ 394 $ 28 $ - $ 164 $ 819 $ 27 $ 1,550 Net income (22) (23) (8) - 62 110 5 124 Total comprehensive income (loss) 37 356 (8) - 70 502 31 988 Net income allocated to non-controlling interests (18) (16) (5) - 16 86 2 65 Year ended December 31, 2017: Revenue $ 123 $ 430 $ 53 $ - $ 135 $ 797 $ 32 $ 1,570 Net (loss) income (34) (20) 18 - 47 89 7 107 Total comprehensive income (loss) (133) 529 126 - 57 236 - 815 Net (loss) income allocated to non-controlling interests (29) (13) 13 - 12 67 3 53 As at December 31, 2017: Property, plant and equipment, at fair value $ 1,667 $ 5,153 $ 2,149 $ - $ 964 $ 5,401 $ 411 $ 15,745 Total assets 1,718 5,430 3,294 - 1,066 6,526 426 18,460 Total borrowings 556 2,040 1,502 - 413 1,858 42 6,411 Total liabilities 628 2,422 1,678 - 432 3,336 63 8,559 Carrying value of non-controlling interests $ 850 $ 1,682 $ 1,138 $ - $ 134 $ 2,424 $ 70 $ 6,298 Year ended December 31, 2018: Revenue $ 157 $ 447 $ 311 $ 38 $ 142 $ 896 $ 21 $ 2,012 Net income 2 17 19 15 56 331 2 442 Total comprehensive income (loss) 95 544 898 25 (16) 1,290 16 2,852 Net income allocated to non-controlling interests 1 9 15 6 14 251 1 297 As at December 31, 2018: Property, plant and equipment, at fair value $ 1,687 $ 5,553 $ 2,322 $ 1,679 $ 875 $ 6,665 $ 253 $ 19,034 Total assets 1,737 5,831 3,725 1,975 982 7,717 293 22,260 Total borrowings 536 1,979 838 924 369 1,744 70 6,460 Total liabilities 582 2,395 1,441 1,933 387 3,548 88 10,374 Carrying value of non-controlling interests $ 900 $ 1,929 $ 1,641 $ 314 $ 124 $ 3,169 $ 52 $ 8,129 Excludes information relating to Isagen which is presented separately. T he total third parties ownership interest in Isagen as of December 31, 2018 was 75.9% and comprised of Brookfield Infrastructure Fund III: 22.9 %, Isagen Institut ional investors 52.5 % and other non-controlling interests: 0.5 %. General partnership interest in a holding subsidiary held by Brookfield and Participating non-controlling interests – in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield Brookfield, as the owner of the 1 % general partnership interest in BRELP held by Brookfield (“GP interest”), is entitled to regular distributions plus an incentive distribution based on the amount by which quarterly distributions exceed specified target levels. To the extent that LP Unit distributions exceed $ 0.375 per LP Unit per quarter, the incentive is 15 % of distributions above this threshold. To the extent that quarterly LP Unit distributions exceed $ 0.4225 per LP Unit, the incentive distribution is equal to 25 % of distributions above this threshold. Con solidated equity includes Redeemable/Exchangeable partnership units and the GP interest. The Redeemable/Exchangeable partnership units are held 100 % by Brookfield, which at its discretion has the right to redeem these units for cash consideration. No Redee mable/Exchangeable partnership units have been redeemed for cash consideration. Since this redemption right is subject to Brookfield Renewable’s right, at its sole discretion, to satisfy the redemption request with LP Units of Brookfield Renewable on a one for one basis, the Redeemable/Exchangeable partnership units are classified as equity in accordance with IAS 32, Financial Instruments: Presentation . The Redeemable/Exchangeable partnership units and GP interest are presented as non-controlling interests since they provide Brookfield the direct economic benefits and exposures to the underlying performance of BRELP. The LP Units issued by Brookfield Renewable and the Redeemable/Exchangeable partnership units issued by its subsidiary BRELP have the same econ omic attributes in all respects, except for the redemption right described above. The Redeemable/Exchangeable partnership units and the GP interest participate in earnings and distributions on a per unit basis equivalent to the per unit participation of th e LP Units of Brookfield Renewable. As at December 31 , 2018 , general partnership units and Redeemable/Exchangeable partnership units outstanding were 2,651,506 (December 31, 2017 : 2,651,506 ) and 129,658,623 (December 31, 2017 : 129,658,623 ), respectivel y. Distributions The composition of the distributions are presented in the following table: (MILLIONS) 2018 2017 General partnership interest in a holding subsidiary held by Brookfield $ 5 $ 5 Incentive distribution 40 30 $ 45 $ 35 Participating non-controlling interests - in a holding subsidiary - Redeemable/ Exchangeable units held by Brookfield $ 255 $ 243 $ 300 $ 278 The following table summarize s certain financial information regarding General partnership interest in a holding subsidiary held by Brookfield and Participating non-controlling intere sts – in a holding subsidiary – R edeemable/Exchangeable units held by Brookfield : (MILLIONS) 2018 2017 2016 For the year ended December 31 : Revenue $ 2,982 $ 2,625 $ 2,452 Net income 403 51 40 Comprehensive income 3,667 1,401 1,369 Net income allocated to (1) : GP interest 1 (1) - Redeemable/Exchangeable partnership units 17 (23) (29) As at December 31 : Property, plant and equipment, at fair value $ 29,025 $ 27,096 Total assets 34,103 30,904 Total borrowings 10,718 11,766 Total liabilities 16,897 16,622 Carrying value of (2) : GP interest 66 58 Redeemable/Exchangeable partnership units 3,252 2,843 Allocated based on weighted-average GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 180.2 million, respectively ( 2017 : 2.7 million, 129.7 million, and 173.5 million, respectively and 2016 : 2.7 million, 129.7 million, and 156.4 million, respectively). Allocated based on outstanding GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 178.8 million, respectively ( 2017 : 2.7 m illion, 129.7 million, and 180.4 million, respectively). Preferred equity Brookfield Renewable’s preferred equity as at December 31 consists of Class A Preference Shares of Brookfield Renewable Power Preferred Equity Inc. (“BRP Equity”) as follows: Earliest Dividends declared for Cumulative permitted the year ended Carrying value as at (MILLIONS, EXCEPT Shares dividend redemption December 31 AS NOTED) outstanding rate (%) date 2018 2017 2018 2017 Series 1 (C$136) 5.45 3.36 Apr 2020 $ 4 $ 4 $ 100 $ 108 Series 2 (C$113) (1) 4.51 4.29 Apr 2020 3 3 83 90 Series 3 (C$249) 9.96 4.40 Jul 2019 8 8 182 197 Series 5 (C$103) 4.11 5.00 Apr 2018 4 4 75 82 Series 6 (C$175) 7.00 5.00 Jul 2018 7 7 128 139 31.03 $ 26 $ 26 $ 568 $ 616 Dividend rate represents annualized distribution based on the most recent quarterly floating rate . The Class A Preference Shares do not have a fixed maturity date and are not redeemable at the option of the holders. As at December 31, 2018 , none of the issued Class A Preference Shares have been redeemed by BRP Equity. Class A Preference Shares – Normal Course Issuer Bid In June 2018, the TSX accepted notice of BRP Equity’s intention to renew the normal course issuer bid in connection with its outstanding Class A Preference Shares for another year to June 26, 2019, or earlier should the repurchases be completed prior to such date. Under this normal course issuer bid, it is permitted to repurchase up to 10 % of the total public float for each respective series of the Class A Preference Shares. Unitholders may receive a copy of the notice, free of charge, by contac ting Brookfield Renewable. No shares have been repurchased as of December 31, 2018 .

PREFERRED LIMITED PARTNERS EQUI

PREFERRED LIMITED PARTNERS EQUITY	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
PREFERRED LIMITED PARTNERS EQUITY	15 . PREFERRED LIMITED PARTNERS’ EQUITY Brookfield Renewable’s preferred limited partners’ equity comprises of Class A Preferred Units as follows: Earliest Distributions declared for Cumulative permitted the year ended Carrying value as at (MILLIONS, EXCEPT Shares distribution redemption December 31 Dec 31 Dec 31 AS NOTED) outstanding rate (%) date 2018 2017 2018 2017 Series 5 (C$72) 2.89 5.59 Apr 2018 $ 4 $ 4 $ 49 $ 49 Series 7 (C$175) 7.00 5.50 Jan 2021 7 8 128 128 Series 9 (C$200) 8.00 5.75 Jul 2021 9 8 147 147 Series 11 (C$250) 10.00 5.00 Apr 2022 9 8 187 187 Series 13 (C$250) 10.00 5.00 Apr 2023 9 - 196 - 37.89 $ 38 $ 28 $ 707 $ 511 On January 16, 2018, Brookfield Renewable issued 10,000,000 Class A Preferred Limited Partnership Units , Series 13 (the “Series 1 3 Preferred Units”) at a price of C$ 25 per unit for gross proceeds of C$ 250 million ($ 201 million). Brookfield Renewable incurred C$ 7 million ($ 5 million) in related transaction costs inclusive of fees paid to underwriters. The holders of the Series 1 3 Pref erred Units are entitled to receive a cumulative quarterly fixed distribution yielding 5.0 % for the initial period ending April 30, 202 3 . Thereafter, the distribution rate will be reset every five years at a rate equal to the greater of: (i) the 5-year Gov ernment of Canada bond yield plus 3. 00 %, and (ii) 5.00%. The holders of the Series 1 3 Preferred Units will have the right, at their op tion, to convert their Series 13 Preferred Units into Class A Preferred Limited Partnership Units, Series 1 4 (the “Series 1 4 Preferred Units”), subject to certain conditions, on April 30, 202 3 and on April 30 every five years thereafter. The holders of Series 1 4 Preferred Units will be entitled to receive floating rate cumulative preferential cash distributions equal to the s um of the three month Government of Canada Treasury Bill r ate plus 3. 00 % . As at December 31, 2018 , none of the Class A, Series 5 Preferred Limited Partnership Units have been redeemed .

LIMITED PARTNERS EQUITY

LIMITED PARTNERS EQUITY	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
LIMITED PARTNERS EQUITY	16 . LIMITED PARTNERS’ EQUITY Limited partners’ equity As at December 31 , 2018 , 178,821,204 LP Units were outstanding (December 31, 2017 : 180,388,361 ) including 56,068,944 (December 31, 2017 : 56,068,944 ) held by Brookfield. Brookfield owns all g eneral partnership interests in Brookfield Renewable representing a 0.01 % interest. During the year ended December 31, 2018 , 289,641 LP Units ( 2017 : 302,037 LP Units) were issued under the distribution reinvestment plan at a total cost of 8 million ( 2017 : $ 10 million). As at December 31 , 2018 , Brookfield Asset Management’s direct and indirect interest of 185,727,567 LP Units and Redeemable/Exchangeable partnership units represents approximately 60 % of Brookfield Renewable on a fully-exchanged basis and the remaining approximate 40 % is held by public investors. On an unexchanged basis, Brookfield holds a 31 % direct limited partnership interest in Brookfield Renewable, a 42 % direct interest in BRELP through the ownership of Redeemable/Exchangeable partnership units and a direct 1 % GP interest in BRELP as at December 31 , 2018 . In December 2018, Brookfield Renewable renewed its normal course issuer bid in connection with its LP Units. Under this normal course issuer bid Brookfield Renewable is permitted to repurchase up to 8.9 million LP Units, representing approximately 5 % of the issued and outstanding LP Units, for capital management purposes. The bid will expire on December 30 , 2019, or earlier should Brookfield Renewable complete its repurchases prior to such date. Under the prior normal course issuer bid that expired on December 28, 2018, Brookfield Renewable had repurchased 1,856,798 LP Units, on the Toronto Stock Exchange and the New York Stock Exchange, at a total cost of $ 51 million (2017: $nil). An additional 20,000 LP Units were repurchased on December 28, 2018 but not cancelled as at December 31, 2018. Distributions The composition of the distributions are presented in the following table: (MILLIONS) 2018 2017 Brookfield $ 110 $ 101 External LP Unitholders 245 227 $ 355 $ 328 In February 2019, unitholder distributions were increased to $ 2.06 per LP Unit on an annualized basis, an increase of $ 0.10 per LP Unit, which will take effect on the distribution payable in March 2019.

GOODWILL

GOODWILL	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
GOODWILL	17 . GOODWILL The following table provides a reconciliation of goodwill: (MILLIONS) Notes Total Balance, as at December 31, 2016 $ 896 Foreign exchange 5 Balance, as at December 31, 2017 $ 901 Acquired through acquisition 3 27 Transfer to Assets held for sale 4 (22) Foreign exchange (78) Balance, as at December 31, 2018 $ 828 The purchase price allocation for Biotherm (Note 3 – Acquisitions ) includes a deferred tax liability of $ 35 million. The deferred tax liabi lity arises because the tax basi s of the Biotherm net assets are significantly lower than their acquisition date fair value. As required by IFRS 3, this deferred tax liability is calculated in accordance with IAS 12, and is not measured at fair value. IAS 12 requires provisions to be made for all differe nces between the carrying value of assets and liabilities other than goodwill acquired in a business combination and their tax base at their nominal amount, irrespective of whether or not this will result in additional (or less) tax being paid or when any tax cash flows may occur. The fair value of the deferred tax liability would be lower than its nominal amount and Brookfield Renewable has determined that goodwill of $ 27 million arises primarily from such difference.

CAPITAL MANAGEMENT

CAPITAL MANAGEMENT	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
CAPITAL MANAGEMENT	18 . CAPITAL MANAGEMENT Brookfield Renewable’s primary capital management objectives are to ensure the sustainability of its capital to support continuing operations, meet its financial obligations, allow for growth opportunities and provide stable distributions to its LP Unitholders. Brookfield Renewable’s capital is monitored through debt to total capitalization ratio on a consolidated and corporate basis, as at December 31, 2018 these ratios were 34 % and 20 %, respectively ( 2017 : 40 % and 24 %, respectively). Brookfield Renewable has provided covenants to certain of its lenders for its corporate borrowings and credit facilities. The covenants require Brookfield Renewable to meet minimum debt to capitalization ratios. Su bsidiaries of Brookfield Renewable have provided covenants to certain of their lenders for their non-recourse borrowings. These covenants vary from one credit agreement to another and include ratios that address debt service coverage. Certain lenders have also put in place requirements that oblige Brookfield Renewable and its subsidiaries to maintain debt and capital expenditure reserve accounts. The consequences to the subsidiaries as a result of failure to comply with their covenants could include a limit ation of distributions from the subsidiaries to Brookfield Renewable, as well as repayment of outstanding debt. Brookfield Renewable is dependent on the distributions made by its subsidiaries to service its debt. As part of the TerraForm Global transaction , Brookfield Renewable acquired assets with non-recourse financings that were in default prior to the acquisition. As at December 31, 2018 , the loans had outstanding principal amounts totaling $ 183 million, and mature between 2026 and 2031 . These loans have remained not in complia nce with certain covenants due to conditions that existed prior to the acquisition of TerraForm Global, including issues with contractors under engineering, procurement and construction contracts. The loan balances relating to the South African Portfolio h ave been classified as Liabilities directly associated with assets held for sale. See Note 4 – Assets held for sale. The remaining balances have been classified as current as at December 31, 2018 in the annual audited consolidated financial statements. These l oans have a total outstanding balance as at December 31, 2018 of $ 13 million. Brookfield Renewable is currently working with all the lenders to cure such defaults and release the restrictions placed on the projects. Except for the aforementioned defaults, Brookfie ld Renewable complied with all material financial covenants as of December 31, 2018 . Brookfield Renewable’s strategy during 2018 , which was unchanged from 2017 , was to maintain the measures set out in the following schedule as at December 31: Corporate Consolidated (MILLIONS) 2018 2017 2018 2017 Corporate borrowings $ 2,334 $ 2,552 $ 2,334 $ 2,552 Non-recourse borrowings - - 8,384 9,214 2,334 2,552 10,718 11,766 Deferred income tax liabilities, net (1) - - 4,049 3,411 Equity Participating non-controlling interest - in operating subsidiaries - - 8,129 6,298 Preferred equity 568 616 568 616 Preferred limted partners' equity 707 511 707 511 Unitholders' equity (2) 7,802 6,857 7,802 6,857 Total capitalization $ 11,411 $ 10,536 $ 31,973 $ 29,459 Debt to total capitalization 20% 24% 34% 40%	[1]
[1]	Deferred income tax liabilities less deferred income tax assets. Unitholder s’ equity includes equity attributable to Limited p artner’s e quity, Redeem able / Exchangeable partnership units, and GP interest.

EQUITY-ACCOUNTED INVESTMENTS

EQUITY-ACCOUNTED INVESTMENTS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
EQUITY-ACCOUNTED INVESTMENTS	19 . EQUITY-ACCOUNTED INVESTMENTS The following table outlines the changes in Brookfield Renewable’s equity-accounted investments (MILLIONS) 2018 2017 2016 Balance, beginning of year $ 721 $ 206 $ 197 Investment 420 469 - Share of net income 68 2 - Share of other comprehensive income 426 56 8 Dividends received (42) (31) (6) Foreign exchange translation and other (24) 19 7 Balance, end of year $ 1,569 $ 721 $ 206 The following tables summarize gross revenues, net income, assets and liabilities of equity-accounted investments in aggregate : (MILLIONS) 2018 2017 2016 For the year ended December 31 Revenue $ 1,305 310 $ 74 Net income (loss) 223 (24) - Share of net income (1) 68 2 - (1) Brookfield Renewable's ownership interest in these entities ranges from 14-50%. (MILLIONS) 2018 2017 As at December 31: Current assets $ 682 $ 477 Property, plant and equipment, at fair value 11,999 8,098 Other assets 608 213 Current liabilities 1,080 687 Non-recourse borrowings 6,078 4,294 Other liabilities 1,197 822

CASH AND CASH EQUIVALENTS

CASH AND CASH EQUIVALENTS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
CASH AND CASH EQUIVALENTS	20 . CASH AND CASH EQUIVALENTS Brookfield Renewable’s cash and cash equivalents as at December 31 are as follows: (MILLIONS) 2018 2017 Cash $ 127 $ 790 Short-term deposits 46 9 $ 173 $ 799

RESTRICTED CASH

RESTRICTED CASH	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
RESTRICTED CASH	21 . RESTRICTED CASH Brookfield Renewable’s restricted cash as at December 31 is as follows: (MILLIONS) Note 2018 2017 Operations $ 119 $ 195 Credit obligations 60 85 Capital expenditures and development projects 2 4 Total 181 284 Less: non-current 23 (45) (103) Current $ 136 $ 181

TRADE RECEIVABLES AND OTHER CUR

TRADE RECEIVABLES AND OTHER CURRENT ASSETS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
TRADE RECEIVABLES AND OTHER CURRENT ASSETS	22 . TRADE RECEIVABLES AND OTHER CURRENT ASSETS Brookfield Renewable’s trade receivables and other current assets as at December 31 are as follows: (MILLIONS) 2018 2017 Trade receivables $ 339 $ 360 Prepaids and others 114 112 Other short-term receivables 109 82 Current portion of contract asset 45 - $ 607 $ 554 As at December 31, 2018 , 74% ( 2017 : 99%) of trade receivables were current. The decrease in current receivables is due to timing of settlement. Brookfield Renewable does not expect issues with collectability of these amounts. Accordingly, as at December 31, 2018 and 2017 an allowance for doubtful accounts for trade receivables was not deemed necessary . Trade receivables are generally on 30-day terms and credit limits are assigned and monitored for all counterparties. In determining the recoverability of trade receivables, management performs a risk analysis considering the type and age of the outstanding recei vables and the credit worthiness of the counterparties. Management also reviews trade receivable balances on an ongoing basis .

OTHER LONG-TERM ASSETS

OTHER LONG-TERM ASSETS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
OTHER LONG-TERM ASSETS	22 . OTHER LONG-TERM ASSETS The composition of Brookfield Renewable’s other long-term assets as at December 31 is presented in the following table : (MILLIONS) Note 2018 2017 Contract asset $ 402 $ - Restricted cash 21 45 103 Acquisition downpayment - 46 Other 58 81 $ 505 $ 230 At December 31, 2018 and 2017 , restricted cash was held primarily to satisfy lease payments and credit agreements. Contract assets are the result of contract amendments made during the year to Brookfield Renewable’s long-term power purchase agreements with Brookfield associated with generating assets in Ontario held by Great Lakes Power Limited and Mississagi Power Trust. The net impact of these changes were offset by changes to Brookfield Renewable’s long-term energy revenue agreement with Brookfield associated with several entities owned by Brookfield Renewable in the United States, however the changes resulted in a difference in timing of cash flows. As a result, the amendments were accounted for in reflection of their substance, with the recognition of contract asset and liability balances and net financing charges to be recognized over the remainder of the term of the agreements. There are no material provisions for expected credit losses on contract assets. See Note 27 – Related party transactions, for additional details regarding Brookfield Renewable’s revenue agreements with Brookfield.

ACCOUNTS PAYABLE AND ACCRUED LI

ACCOUNTS PAYABLE AND ACCRUED LIABILITIES	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
ACCOUNTS PAYABLE AND ACCRUED LIABILITIES	24 . ACCOUNTS PAYABLE AND ACCRUED LIABILITIES Brookfield Renewable’s accounts payable and accrued liabilities as at December 31 are as follows: (MILLIONS) 2018 2017 Operating accrued liabilities $ 263 $ 271 Accounts payable 76 117 Interest payable on corporate and non-recourse borrowings 76 64 Deferred consideration 30 35 LP Unitholders’ distributions, preferred limited partnership unit distributions and preferred dividends payable (1) 30 29 Other 58 26 $ 533 $ 542 Includes amounts payable only to external LP Unitholders. Amounts payable to Brookfield are included in due to related parties.

OTHER LONG-TERM LIABILITIES

OTHER LONG-TERM LIABILITIES	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
OTHER LONG-TERM LIABILITIES	24 . OTHER LONG-TERM LIABILITIES Brookfield Renewable’s other long-term liabilities as at December 31 are comprised of the following: (MILLIONS) Notes 2018 2017 Contract liabilities $ 479 $ 9 Pension obligations 29 80 89 Acquisition related provisions 69 80 Decommissioning retirement obligations 67 85 Concession payment liability 7 9 Commitments for power purchase agreement 6 13 Contingent considerations 3 18 Other 23 41 $ 734 $ 344 Brookfield Renewable has recorded decommissioning retirement obligations associated with certain power generating assets. The decommissioning retirement obligation has been established for hydroelectric, wind and solar operation sites that are expected to be restored between the years 2031 to 2138 . The estimated cost of decommissioning activities is based on a third-party assessment. Contract liabilities are the result of the amendment to the energy revenue agreement between Brookfield and several entities owned by Brookfield Renewable in the United States. See Note 23 – Other long-term assets, for additional details regarding Brookfield Renewable’s contract balances. See Note 27 – Related party transactions, for additional details regarding Brookfield Renewable’s revenue agreements with Brookfield .

COMMITMENTS, CONTINGENCIES AND

COMMITMENTS, CONTINGENCIES AND GUARANTEES	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
COMMITMENTS, CONTINGENCIES AND GUARANTEES	26 . C OMMITMENTS, CONTINGENCIES AND GUARANTEES Commitments In the course of its operations, Brookfield Renewable and its subsidiaries have entered into agreements for the use of water, land and dams. Payment under those agreements varies with the amount of power generated. The various agreements can be renewed and are extendab le up to 2091 . In the normal course of business, Brookfield Renewable will enter into capital expenditure commitments which primarily relate to contracted project costs for various growth initiatives . As at December 31, 2018, Brookfield Renewable had $ 71 m illion ( 2017 : $ 44 million) of capital expenditure commitments outstanding, of which $ 46 million is payable in less than one year, and $ 25 million in two years. As at December 31, 2018 , Brookfield Renewable had commitments for future operating lease payments under non-cancellable leases which fall due as follows: (MILLIONS) 2019 $ 31 2020 29 2021 25 2022 22 2023 18 Thereafter 125 Total $ 250 Contingencies Brookfield Renewable and its subsidiaries are subject to various legal proceedings, arbitrations and actions arising in the normal course of business. While the final outcome of such legal proceedings and actions cannot be predicted with certainty, it is the opinion of management that the resolution of such proceedings and actions will not have a material impact on Brookfield Renewable’s consolidated financial position or results of operations. Brookfield Renewable, on behalf of Brookfiel d Renewable’s subsidiaries, and the subsidiaries themselves have provided letters of credit, which include, but are not limited to, guarantees for debt service reserves, capital reserves, construction completion and performance. The activity on the issued letters of credit by Brookfield Renewable can be found in Note 13 – Borrowings . Brookfield Renewable , along with institutional investors , ha s provided letters of credit, which include, but are not limited to, guarantees for deb t service reserves, capital reserves, construction completion and performance as it relates to interests in the Brookfield Americas Infrastructure Fund , the Brookfield Infrastructure Fund II , and the Brookfield Infrastructure Fund II I . Brookfield Renewable ’s subsidiaries have similarly provided letters of credit, which include, but are not limited to, guarantees for debt service reserves, capital reserves, construction completion and performance . L etters of credit issued by Brookfield Renewable along with i nstitutional investors and its subsidiaries were as at the following dates: (MILLIONS) 2018 2017 Brookfield Renewable along with institutional investors $ 51 $ 76 Brookfield Renewable's subsidiaries 338 468 $ 389 $ 544 Guarantees In the normal course of operations, Brookfield Renewable and its subsidiaries execute agreements that provide for indemnification and guarantees to third- parties of transactions such as business dispositions, capital project purchases, business acquisitions, and sales and purchases of assets and services. Brookfield Renewable has also agreed to indemnify its directors and certain of its officers and employees. The nature of substantially all of t he indemnification undertakings prevents Brookfield Renewable from making a reasonable estimate of the maximum potential amount that Brookfield Renewable could be required to pay third parties as the agreements do not always specify a maximum amount and th e amounts are dependent upon the outcome of future contingent events, the nature and likelihood of which cannot be determined at this time. Historically, neither Brookfield Renewable nor its subsidiaries have made material payments under such indemnificati on agreements.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
RELATED PARTY TRANSACTIONS	27 . RELATED PARTY TRANSACTIONS Brookfield Renewable’s related party transactions are recorded at the exchange amount. Brookfield Renewable’s related party transactions are primarily with Brookfield . Brookfield Renewable and Brookfield have entered into, or amended, the following material agreements: Principal Agreements Limited Partnership Agreements Each of the amended and restated limited partnership agreements of Brookfield Renewable and BRELP outline the key terms of the partnerships, including provisions relating to management, protections for limited partners, capital contributions, distributions and allocation of income and losses. BRELP’s general partner is entitled to receive incentive dis tributions from BRELP as a result of its ownership of the general partnership interest in BRELP. The incentive distributions are to be calculated in increments based on the amount by which quarterly distributions on the limited partnership units of BRELP e xceed specified target levels as set forth in the amended and restated partnership agreement. Master Services Agreement Brookfield Renewable entered into an agreement with Brookfield Asset Management pursuant to which Brookfield Asset Management has agreed to provide oversight of the business and provide the services of senior officers to Brookfield Renewable for a management service fee. The fee is paid on a quarterly basis and has a fixed quarterly component of $ 5 million and a variable component calcula ted as a percentage of the increase in the total capitalization value of Brookfield Renewable over an initial reference value (subject to an annual escalation by a specified inflation factor beginning on January 1, 2013). Total capitalization value as of D ecember 31, 2018 is $ 16 billion, which against the initial reference value of $ 8 billion and factoring in the annual amount of $ 21 million (as adjusted for inflation), resulted in a management service fee payment for the year ended December 31, 2018 of $ 80 million (2017: $ 82 million and 2016: $ 62 million). BRELP Voting Agreement In 2011, Brookfield Renewable entered into a voting agreement with Brookfield pursuant to which Brookfield Renewable, through BRPL, has a number of voting rights, including the right to direct all eligible votes in the election of the directors of BRELP’s general partner. Power Services Agreements Energy Marketing Internalization On October 30, 2018, Brookfield Renewable and Brookfield entered into an agreement (the “Power Marketing Purchase Agreement”) to internalize all energy marketing capabilities in No rth America into Brookfield Renewable. The Power Marketing Purchase Agreement provides for the transfer of Brookfield’s existing marketing business to Brookfield Renewable, which includes the marketing, purchasing and trading of energy and energy related p roducts in North America, providing energy marketing services and all matters incidental thereto (the “Energy Marketing Internalization”). The Energy Marketing Internalization will also include transfer of all third party power purchase agreements and , subject to certain exceptions, rel ated party power purchase and revenue support agreements as described in further detail below. The closing of the Energy Marketing Internalization is targeted to occur in the first half of 2019, subject to the satisfaction of customary closing conditions. It is anticipated that on closing of the Energy Marketing Internalization, Brookfield Renewable and Brookfield will enter into an agreement pursuant to which Brookfield Renewable will provide energy marketing services to Br ookfield for a fee. Also on October 30, 2018, Brookfield Renewable and Brookfield separately amended certain related party agreements, as described in further detail below. Power Agency Agreements Certain Brookfield Renewable subsidiaries have entered into Power Agency Agreements appointing Brookfield as their exclusive agent in respect of the sales of electricity, including the procurement of transmission and other additional services. In addition , Brookfield will schedule, dispatch and arrange for transmission of the power produced and the power supplied to third-parties in accordance with prudent industry practice. Pursuant to each Agreement, Brookfield will be entitled to be reimbursed for any t hird party costs incurred, and, in certain cases, receives an additional fee for its services in connection with the sale of power and for providing the other services. On closing of the Energy Marketing Internalization, all Power Agency Agreements will b e transferred by Brookfield to Brookfield Renewable. Energy Marketing Agreement Brookfield has agreed to provide energy marketing services to Brookfield Renewable’s North American businesses. Under this Agreement, Brookfield Renewable pays an annual energy marketing fee of $ 18 million per year (subject to increase by a specified inflation factor beginning on January 1, 2013). See Note 8 - Direct operating costs. On closing of the Energy Marketing Internalization, the Energy Marketing Agreement will be transferred from Brookfield to Brookfield Renewable. Revenue Agreements Contract Amendments In 2018, two long-term power purchase agreements associated with the generating assets in Ontario held by Great Lakes Power Limited (“GLPL”) and Mississagi Power Trust (“MPT”), were amended. The amended GLPL power purchase agreement requires Brookfield to purchase the energy generated by certain facilities in Canada owned by GLPL at an average price of C$ 100 per MWh subject to an annual adjustment equal to a 3 % fixed rate. The GLPL agreement has an initial term to 2029 , and Brookfield Renewable will have an option to e xtend a fixed price commitment to GLPL from Brookfield Asset Management through 2044 at a price of C$ 60 per MWh. The amended MPT power purchase agreement requires Brookfield to purchase the energy generated by certain facilities in Canada owned by MPT at a n average price of C$ 127 per MWh subject to an annual adjustment equal to a 3 % fixed rate. The MPT contract terminates on December 1, 2029 . Energy Revenue Agreement In 2018, the energy revenue agreement between Brookfield and several entities owned by Broo kfield Renewable was effectively amended. Brookfield will support the price that Brookfield Renewable receives for energy generated by certain facilities in the United States at a price $ 75 per MWh. This price is to be increased annually on January 1 unti l 2021 by an amount equal to 40 % of the increase in the CPI during the previous calendar year, but not exceeding an increase of 3 % in any calendar year. The price will be reduced by $ 3 per MWh per year from 2021 to 2025 and then further reduced by $ 5.03 pe r MWh in 2026 . The energy revenue agreement will terminate in 2046 . Other Revenue Agreements Pursuant to a 20-year power purchase agreement, Brookfield purchases all energy from several power facilities in Maine and New Hampshire held by Great Lakes Holdin g America (“GLHA”) at $ 37 per MWh. The energy rates are subject to an annual adjustment equal to 20 % of the increase in the CPI during the previous year. On closing of the Energy Marketing Internalization, the power purchase agreement with GLHA will be tr ansferred to Brookfield Renewable. Pursuant to a 20-year power purchase agreement, Brookfield purchases all energy from Lievre Power in Quebec at C$ 68 per MWh. The energy rates are subject to an annual adjustment equal to the lesser of 40 % of the increase in the CPI during the previous calendar year or 3 %. On closing of the Energy Marketing Internalization, the power purchase agreement with Lievre Power will be transferred to Brookfield Renewable. Pursuant to a power guarantee agreement, B rookfield will purchase all energy from the two facilities of Hydro Pontiac Inc. at a price of C$ 68 per MWh, to be increased annually each calendar year beginning in 2010 by an amount equal to 40 % of the increase in the CPI during the previous calendar yea r. This power guarantee agreement is scheduled to commence in 2019 for one facility and in 2020 for the other, upon the expiration of existing third-party power agreements. The agreement with Brookfield has an initial term to 2029 and automatically renews for successive 20-year period with certain termination provisions. On closing of the Energy Marketing Internalization, the power guarantee agreement with Hydro Pontiac Inc. will be transferred to Brookfield Renewable. Pursuant to a 10-year Wind Levelizatio n agreement expiring in 2019 , Brookfield mitigates any potential wind variation from the expected annual generation of 506 GWh with regards to the Prince Wind assets in Ontario. Any excess generation compared to the expected generation results in a payment from Brookfield Renewable to Brookfield, while a shortfall would result in a payment from Brookfield to Brookfield Renewable. Voting Agreements Brookfield Renewable entered into voting agreements with Brookfield whereby Brookfield, as managing member of entities related to the Brookfield Americas Infrastructure Fund (the “BAIF Entities”) in which Brookfield Renewable holds investments in power generating operations with institutional investors, agreed to assign to Brookfield Renewable their voting rights to elect the Boards of Directors of the BAIF Entities. Brookfield Renewable’s economic interests in the BAIF Entities in the United States and Brazil are 22 % and 25 %, respectively. Brookfield Renewable entered into voting agreements with certain Brookfiel d subsidiaries whereby these subsidiaries, as managing members of entities related to Brookfield Infrastructure Fund II (the “BIF II Entities”) in which Brookfield Renewable holds investments in power generating operations with institutional investors, agr eed to provide to Brookfield Renewable the authority to direct the election of the Boards of Directors of the BIF II Entities. Brookfield Renewable’s economic interests in the BIF II Entities are between 40 % and 50.1 %. Except as set out below in respect to TerraForm Power and Isagen, Brookfield Renewable entered into a voting agreement with certain Brookfield subsidiaries that form part of Brookfield Infrastructure Fund III (the “BIF III Entities”) in which Brookfield Renewable holds investments in power ge nerating operations with institutional investors, Brookfield agreed to provide to Brookfield Renewable the authority to direct the election of the Boards of Directors of the BIF III Entities. Brookfield Renewable’s economic interests in the BIF III Entitie s are between 24 % and 31 %. The consortium holds its interest in Isagen through an entity (“Hydro Holdings”) which is entitled to appoint a majority of the board of directors of Isagen. The general partner of Hydro Holdings is a controlled subsidiary of Br ookfield Renewable. Brookfield Renewable is entitled to appoint a majority of Hydro Holdings’ board of directors, provided that Brookfield Asset Management and its subsidiaries (including Brookfield Renewable) collectively are (i) the largest holder of Hy dro Holdings’ limited partnership interests, and (ii) hold over 30 % of Hydro Holdings’ limited partnership interests (the “Ownership Test”). Brookfield Asset Management and its subsidiaries currently meet the Ownership Test. Brookfield Renewable entered i nto a voting agreement with the Brookfield subsidiary that ultimately controls TerraForm Power. Pursuant to this voting agreement, Brookfield Renewable is entitled to direct the election of one of the four directors of the Brookfield subsidiary, thereby pr oviding Brookfield Renewable with significant influence over this subsidiary. The following table reflects the related party agreements and transactions in the consolidated statements of income , for the year ended December 31: (MILLIONS) 2018 2017 2016 Revenues Power purchase and revenue agreements $ 535 $ 601 $ 527 Wind levelization agreement 7 6 8 $ 542 $ 607 $ 535 Direct operating costs Energy purchases $ (20) $ (13) $ (3) Energy marketing fee (24) (24) (23) Insurance services (25) (19) (20) $ (69) $ (56) $ (46) Interest (expense) income - borrowings $ (8) $ - $ 6 Management service costs $ (80) $ (82) $ (62) The following table reflects the impact of the related party agreements and transactions on the consolidated statements of financial position as at December 31: (MILLIONS) Related party 2018 2017 Current assets Contract asset Brookfield $ 45 $ - Due from related parties Amounts due from Brookfield 55 54 Equity-accounted investments and other 10 6 $ 110 $ 60 Non-current assets Contract asset Brookfield $ 402 $ - Current liabilities Due to related parties Amount due to Brookfield $ 54 $ 48 Equity-accounted investments and other 12 32 Accrued distributions payable on LP Units and Redeemable/ Exchangeable partnership units Brookfield 35 32 $ 101 $ 112 Non-current liabilities Contract liability Brookfield $ 479 9 Current assets Amounts due from Brookfield are non-interest bearing, unsecured and due on demand. Current liabilities Amounts due to Brookfield are unsecured, payable on demand and relate to recurring transactions.

SUPPLEMENTAL INFORMATION

SUPPLEMENTAL INFORMATION	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
SUPPLEMENTAL INFORMATION	27 . SUPPLEMENTAL INFORMATION The net change in working capital balances for the year ended December 31 shown in the consolidated statements of cash flows is comprised of the following: (MILLIONS) 2018 2017 2016 Trade receivables and other current assets $ (122) $ (40) $ 30 Accounts payable and accrued liabilities 32 32 (160) Other assets and liabilities 22 (17) (7) $ (68) $ (25) $ (137)

PENSION AND EMPLOYEE FUTURE BEN

PENSION AND EMPLOYEE FUTURE BENEFITS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
PENSION AND EMPLOYEE FUTURE BENEFITS	29 . PENSION AND EMPLOYEE FUTURE BENEFITS Brookfield Renewable offers a number of pension plans to its employees, as well as certain health care, dental care, life insurance and other benefits to certain retired employees pursuant to Brookfield Renewable’s policy. The plans are funded by contributions from Brookfield Renewable and from plan members. Pension benefits are based on length of service and final average earnings and some plans are indexed for inflation after retirement. The pension p lans relating to employees of Brookfield Renewable have been included in the consolidated financial statements. The Brookfield Renewable Pension Governance Committee (BRGC) is responsible for the implementation of strategic decisions and monitoring of the administration of Brookfield Renewable ’s defined benefit pension plans. Specifically, the BRGC will establish the investment strategies, approve the funding policies as well as assess that Brookfield Renewable has complied with all applicable law, fiduci ary, reporting and disclosure requirements. Actuarial valuations for Brookfield Renewable’s pension plans are required as per governing provincial or federal regulations. For the United States registered plans, actuarial valuations are required annually. F or the Canadian registered plans, actuarial valuations are required on a triennial basis if the funding level of the plan is above a certain threshold. Currently, all Canadian plans are on a triennial schedule. In the Colombian business , there are obligati ons for pension plan s and other employee benefits. Actuarial valuations on these obligations are performed annually by qualified, independent actuaries. The dates of the most recent actuarial valuations for Brookfield Renewable’s pension and non-pension b enefit plans range from January 2016 to January 2018. Brookfield Renewable measures its accrued benefit obligations and the fair value of plan assets for accounting purposes as at December 31 of each year. The benefit liabilities represent the amount of pe nsion and other employee future benefits that Brookfield Renewable’s employees and retirees have earned at year-end. The benefit obligation under these plans is determined through periodic actuarial reports which were based on the assumptions indicated in the following table. Actuarial assumptions as at December 31: (%) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Discount rate 2.5 - 7.2 3.9 - 7.4 2.4 - 7.3 3.7 - 7.1 2.2 - 7.3 4.1 - 7.3 Rate of price inflation 1.5 - 3.5 N/A 1.5 - 3.5 N/A 1.5 - 3.5 N/A Rate of compensation increases 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 Health care trend rate (1) N/A 5.3 - 6.9 N/A 5.3 - 6.9 N/A 5.3 - 6.9 Assumed immediate trend rate at year-end. Plan obligations and the annual pension expense are determined on an actuarial basis and are affected by numerous assumptions and estimates including the market value of plan assets, discount rates, rate of compensation increases and other assumptions. The discount rate, rate of price inflation and inflation-linked assumptions and health care cost trend rate are the assumptions that generally have the most significant impact on the benefit obligations. The discount rate for benefit obligation purposes i s determined, as far as possible, by reference to market yields on high quality corporate bonds. In Colombia deep market in bonds does not exist. A ccordingly, the discount rate is determined by reference to yields on government bonds. Rate of compensation increases reflect the best estimate of merit increases to be provided, consistent with assumed inflation rates. A 50 basis point change in the assumptions mentioned before, used for the calculation of the benefit obligations as at December 31, 2018 , would result in the following increase (decrease) of the benefit obligations: Defined benefit Non-pension (MILLIONS) pension plans benefit plans Discount rate 50 basis point increase $ (7) $ (4) 50 basis point decrease 8 4 Rate of price inflation and inflation-linked assumptions 50 basis point increase 4 N/A 50 basis point decrease (4) N/A Health care cost trend rate 50 basis point increase N/A 3 50 basis point decrease N/A (3) The sensitivity analysis presented above may not be representative of the actual change in the defined benefit obligation as it is unlikely that the change in assumptions would occur in isolation of one another as some of the assumptions may be correlated. (MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Current service costs $ 3 $ 2 $ 3 $ 1 $ 3 $ 1 Past service costs (recovery) - - (1) - - - Interest expense 2 3 2 3 2 3 Administrative expenses 1 - 1 - 1 - Recognized in consolidated statement of income 6 5 5 4 6 4 Remeasurement of the net defined benefit liability: Return on plan assets 5 - (8) - (2) - Actuarial changes arising from changes in demographic assumptions (1) - 1 (2) (1) (1) Actuarial changes arising from changes in financial assumptions (9) (4) 7 3 5 1 Experience adjustments 1 (1) - 1 - - Recognized in consolidated statement of comprehensive income (4) (5) - 2 2 - Total $ 2 $ - $ 5 $ 6 $ 8 $ 4 The amounts included in the consolidated statements of financial position arising from Brookfield Renewable’s obligations in respect of its defined benefit plans are as follows: (MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Present value of defined benefit obligation $ 157 $ 53 $ 172 $ 57 $ 158 $ 53 Fair value of plan assets (126) (4) (135) (5) (119) (5) Net liability $ 31 $ 49 $ 37 $ 52 $ 39 $ 48 Defined benefit obligations The movement of the defined benefit obligation for the year ended December 31 is as follows: (MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Balance, beginning of year $ 172 $ 57 $ 158 $ 53 $ 124 $ 35 Current service cost 3 2 3 1 3 1 Past service (recovery) cost - - (1) - - - Interest expense 7 3 7 3 7 3 Remeasurement losses (gains) Actuarial changes arising from changes in demographic assumptions (1) - 1 (2) (1) (1) Actuarial changes arising from changes in financial assumptions (9) (4) 7 3 5 1 Experience adjustments 1 (1) - 1 - - Benefits paid (9) (2) (7) (2) (8) (2) Business combination - - - - 25 14 Exchange differences (7) (2) 4 - 3 2 Balance, end of year $ 157 $ 53 $ 172 $ 57 $ 158 $ 53 Expected employer’s contributions to the defined benefit plans for the year ended December 31, 2019 are $ 10 million. Fair value of plan assets The movement in the fair value of plan assets for the year ended December 31 is as follows: (MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Balance, beginning of year $ 135 $ 5 $ 119 $ 5 $ 103 $ - Interest income 5 - 5 - 5 - Return on plan assets (5) (1) 8 - 2 - Employer contributions 5 2 5 2 7 3 Business combination - - - - 9 4 Benefits paid (9) (2) (7) (2) (8) (2) Exchange differences (5) - 5 - 1 - Balance, end of year $ 126 $ 4 $ 135 $ 5 $ 119 $ 5 The composition of plan assets as at December 31 are as follows: (%) 2018 2017 Asset category: Cash and cash equivalents 2 2 Equity securities 47 54 Debt securities 51 44 100 100

SUBSIDIARY PUBLIC ISSUERS

SUBSIDIARY PUBLIC ISSUERS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
SUBSIDIARY PUBLIC ISSUERS	29 . SUBSIDIARY PUBLIC ISSUERS The following tables provide consolidated summary financial information for Brookfield Renewable, BRP Equity, and Finco : Brookfield Brookfield BRP Holding Other Consolidating Renewable (MILLIONS) Renewable (1) Equity Finco Entities (1)(2) Subsidiaries (1)(3) adjustments (4) consolidated As at December 31, 2018: Current assets $ 32 $ 389 $ 1,631 $ 93 $ 3,639 $ (3,823) $ 1,961 Long-term assets 5,208 239 1 24,078 32,433 (29,817) 32,142 Current liabilities 38 6 21 3,096 2,351 (3,823) 1,689 Long-term liabilities - - 1,607 798 13,445 (642) 15,208 Participating non-controlling interests - in operating subsidiaries - - - - 8,129 - 8,129 Participating non-controlling interests -in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield - - - 3,252 - - 3,252 Preferred equity - 568 - - - - 568 Preferred limited partners' equity 707 - - 718 - (718) 707 As at December 31, 2017: Current assets $ 32 $ 412 $ 1,691 $ 525 $ 2,816 $ (3,810) $ 1,666 Long-term assets 4,483 262 - 20,142 29,508 (25,157) 29,238 Current liabilities 43 7 180 3,024 3,071 (3,811) 2,514 Long-term liabilities - - 1,505 693 12,670 (760) 14,108 Participating non-controlling interests - in operating subsidiaries - - - - 6,298 - 6,298 Participating non-controlling interests -in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield - - - 2,843 - - 2,843 Preferred equity - 616 - - - - 616 Preferred limited partners' equity 511 - - 516 - (516) 511 Includes investments in subsidiaries under the equity method. Includes BRELP, BRP Bermuda Holdings I Limited, Brookfield BRP Holdings (Canada) Inc. and Brookfield BRP Europe Holdings Limited, together the “Holding Entities”. Includes subsidiaries of Brookfield Renewable , other than BRP Equity , Finco and the Holding Entities . Includes elimination of intercompany transactions and balances necessary to present Brookfield Renewable on a consolidated basis . Brookfield Brookfield BRP Holding Other Consolidating Renewable (MILLIONS) Renewable (1) Equity Finco Entities (1)(2) Subsidiaries (1)(3) adjustments (4) consolidated For the year ended December 31, 2018 Revenues $ - $ - $ - $ - $ 2,983 $ (1) $ 2,982 Net income (loss) 62 7 (1) (25) 1,305 (945) 403 For the year ended December 31, 2017 Revenues $ - $ - $ - $ - $ 2,625 $ - $ 2,625 Net income (loss) (4) 10 (1) (435) 631 (150) 51 For the year ended December 31, 2016 Revenues $ - $ - $ - $ 1 $ 2,451 $ - $ 2,452 Net income (loss) (20) - (1) (100) 558 (397) 40 Includes investments in subsidiaries under the equity method. Includes the Holding Entities . Includes subsidiaries of Brookfield Renewable , other than BRP Equity , Finco, and the Holding Entities . Includes elimination of intercompany transactions and balances necessary to present Brookfield Renewable on a consolidated basis. See Note 13 – Borrowings for additional details regarding the medium-term corporate notes issued by Finco. See Note 15 – Non-c ontrolling i nterests for additional details regarding Class A Preference Shares issued by BRP Equity.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2018
Disclosure Text Block [Abstract]
SUBSEQUENT EVENTS	On February 25, 2019, Brookfield Renewable completed a C$ 70 ($ 53 million) non-recourse financing associated with a 20 MW hydroelectric facility in Ontario. The debt bears an interest rate of 4.13 % and matures in 2045 . In February 2019, Brookfield Renewable entered into an agreement to sell an additional 25 % non-controlling, indirect interest in a 413 MW portfolio of select Canadian hydroelectric assets to a consortium of buyers for the same price, subject to an adjustme nt for an approximate $ 50 million dividend recapitalization completed in the fourth quarter of 2018, as our initial 25% non-controlling, direct interest sale, the closing of which remains subject to the satisfaction of customary conditions. Following closi ng, Brookfield Renewable will retain a 50 % economic interest in this portfolio and will continue to have the responsibility to manage and operate the assets in the portfolio.

BASIS OF PREPARATION AND SIGN_2

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (POLICY)	12 Months Ended
	Dec. 31, 2018
Policy Text Block [Abstract]
Statement Of IFRS Compliance	a) Statement of compliance The consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”). The accounting policies used in the consolidated financial statements are based on the IFRS applicable as at December 31, 2018, which encompass individual IFRS, International Accounting Standards (“IAS”), and interpret ations made by the International Financial Reporting Interpretations Committee (“IFRIC”) and the Standard Interpretations Committee (“SIC”). The policies set out below are consistently applied to all periods presented, unless otherwise noted. These conso lidated financial statements have been authorized for issuance by the Board of Directors of Brookfield Renewable’s general partner, BRPL , on February 28, 2019 . Certain comparative figures have been reclassified to conform to the current year’s presentation. References to $, C$, € , £ ,R $, COP , ZAR, THB and MYR are to United States (“U.S.”) dollars, Canadian dollars, Euros, British p ound sterling , Brazilian reais , Colombian pesos, South African rand, Thai baht and Malaysian ringgit, respectively. All figures are presented in millions of U.S. dollars unless otherwise noted.
Basis of presentation - Consolidation	These consolidated financial statements include the accounts of Brookfield Renewable and its subsidiaries, which are the entities over which Brook field Renewable has control. An investor controls an investee when it is exposed, or has rights, to variable returns from its involvement with the investee and has the ability to affect those returns through its power over the investee. Non-controlling int erests in the equity of Brookfield Renewable’s subsidiaries are shown separately in equity in the consolidated statements of financial position. Brookfield Renewable has entered into a voting agreement with Brookfield, which provides Brookfield Renewable w ith control of the general partner of Brookfield Renewable Energy L.P. (“BRELP”), a holding subsidiary. Accordingly, Brookfield Renewable consolidates the accounts of BRELP and its subsidiaries. In addition, BRELP issued redeemable/exchangeable limited par tnership units to Brookfield (“Redeemable/Exchangeable Partnership Units”), pursuant to which the holder may at its request require BRELP to redeem the Redeemable/Exchangeable Partnership Units for cash consideration. This right is subject to Brookfield Re newable’s right of first refusal which entitles it, at its sole discretion, to elect to acquire all of the Redeemable/Exchangeable Partnership Units so presented to BRELP that are tendered for redemption in exchange for LP Units on a one for one basis . As Brookfield Renewable, a t its sole discretion, has the right to settle the obligation with LP Units, the Redeemable/Exchangeable Partnership Units are classified as equity of Brookfield Renewable (“Participating non-controlling interests – in a holding subsidiary – Redeemable/Exc hangeable Units held by Brookfield”). Brookfield Renewable has entered into voting agreements with Brookfield, whereby Brookfield Renewable gained control of the entities that own certain renewable power generating operations in the United States, Brazil, Europe and other countries (including India and China). Brookfield Renewable has also entered into a voting agreement with our consortium partners in respect of our Colombian operations. These voting agreements provide Brookfield Renewable the authority to direct the election of the Boards of Directors of the relevant entities, among other things, and therefore provide Brookfield Renewable with control. Accordingly, Brookfield Renewable consolidates the accounts of these entities. Refer to Note 27 - Relat ed party transactions for further information. For entities previously controlled by Brookfield Asset Management, the voting agreements entered into do not represent business combinations in accordance with IFRS 3, Business Combinations (“ IFRS 3” ) , as all combining businesses are ultimately controlled by Brookfield Asset Management both before and after the transactions were completed. Brookfield Renewable accounts for these transactions involving entities under common control in a manner similar to a pooli ng of interest, which requires the presentation of pre-voting agreement financial information as if the transactions had always been in place. Refer to Note 1(r)(ii) - Critical judgments in applying accounting policies - Common control transactions for Bro okfield Renewable’s policy on accounting for transactions under common control.
Basis of presentation - Equity-accounted investments and joint ventures	Equity-accounted investments are entities over which Brookfield Renewable has significant influence or joint arrangements representing jo int ventures. Significant influence is the ability to participate in the financial and operating policy decisions of the investee, but without controlling or jointly controlling those investees. Such investments are accounted for using the equity method. A joint venture is a type of joint arrangement whereby the parties that have joint control of the arrangement have rights to the net assets of the joint venture. Joint control is the contractually agreed sharing of control of an arrangement, which exists o nly when decisions about the relevant activities require unanimous consent of the parties sharing control. Brookfield Renewable accounts for its interests in joint ventures using the equity method. Under the equity method, the carrying value of an interes t in an investee is initially recognized at cost and adjusted for Brookfield Renewable’s share of net income, other comprehensive income (“OCI”), distributions by the equity-accounted investment and other adjustments to Brookfield Renewable’s proportionate interest in the investee.
Foreign currency translation	All figures reported in the consolidated financial statements and tabular disclosures to the consolidated financial statements are reflected in millions of U.S. dollars, which is the functional currency of Brookfield Renewable. Each of the foreign operations included in these consolidated financial statements determines its own functional currency, and items included in the financial statements of each subsidiary are measured using that functional currency. Assets and liabilities of foreign operations having a functional currency other than the U.S. dollar are translated at the rate of exchange prevailing at the reporting date and revenues and expenses at the rate of exchange prevailing at the dates of the transactions during the period. Gains or losses on translation of foreign subsidiaries are included in OCI. Gains or losses on foreign currency denominated balances and transactions that are designated as hedges of net investments in these operations are reported in th e same manner. In preparing the consolidated financial statements of Brookfield Renewable, foreign currency denominated monetary assets and liabilities are translated into the functional currency using the closing rate at the applicable consolidated statem ent of financial position dates. Non-monetary assets and liabilities, denominated in a foreign currency and measured at fair value, are translated at the rate of exchange prevailing at the date when the fair value was determined and non-monetary assets mea sured at historical cost are translated at the historical rate. Revenues and expenses are measured in the functional currency at the rates of exchange prevailing at the dates of the transactions with gains or losses included in income.
Cash and cash equivalents	Cash and cash equivalents include cash, term deposits and money market instruments with original maturities of less than 90 days.
Restricted cash	Restricted cash includes cash and cash equivalents, where the availability of funds is restric ted primarily by credit agreements.
Property, plant and equipment and revaluation method	Power generating assets are classified as property, plant and equipment and are accounted for using the revaluation method under IAS 16, Property, Plant and Equipm ent (“IAS 16”). Property, plant and equipment are initially measured at cost and subsequently carried at their revalued amount, being the fair value at the date of the revaluation, less any subsequent accumulated depreciation and any subsequent accumulated impairment losses. Brookfield Renewable generally determines the fair value of its property, plant and equipment by using a 20-year discounted cash flow model for the majority of its assets . This model incorporates future cash flows from long-term power purchase agreements that are in place where it is determined that the power purchase agreements are linked specifically to the related power generating assets. The model also includes estimates of future electricity prices, anticipated long-term average generation, estimated operating a nd capital expenditures, and assumptions about future inflation rates and discount rates by geographical location. Construction work-in-progress (“CWIP”) is revalued when sufficient information exists to determine fair value using the discounted cash flow method. Revaluations are made on an annual basis as at December 31 to ensure that the carrying amount does not differ significantly from fair value. For power generating assets acquired through business combinations during the year, Brookfield Renewable in itially measures the assets at fair value consistent with the policy described in Note 1(n) – Business combinations. Accordingly, in the year of acquisition, power generating assets are not revalued at year-end unless there is an indication that assets are impaired. Where the carrying amount of an asset increased as a result of a revaluation, the increase is recognized in income to the extent the increase reverses a previously recognized decrease recorded through income, with the remainder of the increase r ecognized in OCI and accumulated in equity under revaluation surplus and non-controlling interest. Where the carrying amount of an asset decreased, the decrease is recognized in OCI to the extent that a balance exists in revaluation surplus with respect to the asset, with the remainder of the decrease recognized in income.
Property, plant and equipment - Depreciation	Depreciation on power generating assets is calculated on a straight-line basis over the estimated service lives of the assets, which are as follows: Estimated service lives Dams Up to 115 years Penstocks Up to 60 years Powerhouses Up to 115 years Hydroelectric generating units Up to 115 years Wind generating units Up to 30 years Solar generating units Up to 30 years Gas-fired cogenerating (“Cogeneration”) units Up to 40 years Other assets Up to 60 years Costs are allocated to significant components of property, plant and equipment. When items of property, plant and equipment have different useful lives, they are accounted for as separate items (significant components) and depreciated separately. To ensure the accuracy of useful lives and residual values, a review is conducted annually. Depreciation is calculated based on the cost of the asset less its residual value. Depreciation commences when the asset is in the location and condit ions necessary for it to be capable of operating in the manner intended by management. It ceases at the earlier of the date the asset is classified as held-for-sale and the date the asset is derecognized. An item of property, plant and equipment and any si gnificant component is derecognized upon disposal or when no future economic benefits are expected from its use. Other assets include equipment, buildings and leasehold improvements. Buildings, furniture and fixtures, leasehold improvements and office equi pment are recorded at historical cost, less accumulated depreciation. Land and CWIP are not subject to depreciation. The depreciation of property, plant and equipment in Brazil is based on the duration of the authorization or the useful life of a concess ion asset. The weighted-average remaining duration at December 31, 2018 is 29 years ( 2017 : 15 years). Since land rights are part of the concession or authorization, this cost is also subject to depreciation. In June of 2018, the federal government of Brazil provided further clarification to a law that was passed in 2016, which resulted in Brookfield Renewable including a one-time thirty year concession renewal period in the valuation of certain of its hydroelectric facilities in Brazil. Any accumul ated depreciation at the date of revaluation is eliminated against the gross carrying amount of the asset, and the net amount is applied to the revalued amount of the asset. Gains and losses on disposal of an item of property, plant and equipment are recog nized in Other income in the consolidated statements of income. The revaluation surplus is reclassified within the respective components of equity and not reclassified to net income when the assets are disposed.
Asset impairment	At each statement of fi nancial position date, management assesses whether there is any indication that assets are impaired. For non-financial tangible and intangible assets (including equity-accounted investments), an impairment is recognized if the recoverable amount, determine d as the greater of the estimated fair value, less costs to sell, and the discounted future cash flows generated from use and eventual disposal of an asset or cash-generating unit, is less than its carrying value. The projections of future cash flows take into account the relevant operating plans and management’s best estimate of the most probable set of conditions anticipated to prevail. Should an impairment loss subsequently reverse, the carrying amount of the asset is increased to the lesser of the revis ed estimate of the recoverable amount, and the carrying amount that would have been recorded had no impairment loss been recognized previously.
Trade receivables and other current assets	Trade receivables and other current assets are recognized initial ly at fair value, and subsequently measured at amortized cost using the effective interest method, less any provision for expected credit losses.
Financial instruments	(d) C hanges to and impact of financial instrument accounting policies Classification and measurement Under IFRS 9, financial assets are subsequently measured at fair value through profit or loss, amortiz ed cost, or fair value through OCI. The classification is based on two criteria: Brookfield Renewable’s business objectives for managing the assets; and whether the instruments’ contractual cash flows represent ‘solely payments of principal and interest’ on the principal amount outstanding. The assessment of Brookfield Renewable’s business objectives was made as of January 1, 2018, the date of initial application. The assessment of whether contractual cash flows on debt instruments are solely comprised of pri ncipal and interest was made based on the facts and circumstances as at the initial recognition of the assets. The following accounting policies are applicable to the accounting for financial in struments from January 1, 2018 under IFRS 9 . The impact to the Consolidated Financial Statements of the adoption of IFRS 9 in the current period and comparison to IAS 39 applied in the comparati ve period is explained in Note 1 (d) - Changes to and I mpact of F inancial I nstrument A ccounting P olicies . Initial recognition Under IFRS 9, regular purchases and sales of financial assets are recognized on the trade date, being the date on which Brookfield Renewable commits to purchase or sell the asset. Financial assets are derecognized when the rights to receive cash flows from the financial assets have expired or have been transferred and Brookfield Renewable has transferred substantially all the risks and rewards of ownership. At initial recognition, Brookfield Renewable measures a financial asset at its fair value. In the case of a financial asset not categorized as FVPL, transaction costs that are directly attributable to the acquisition of the financial asset are included at initial recognition. Transaction co sts of financial assets carried at FVPL are expensed in profit or loss. Classification and measurement Subsequent measurement of financial assets depends on Brookfield Renewable’s business objective for managing the asset and the cash flow characteristics of the asset. There are three measurement categories into which Brookfield Renewable classifies its financial assets: Amortized cost – Financial a ssets held for collection of contractual cash flows that represent solely payments of principal and interest a re measured at amortized cost. Interest income is recognized as other income in the financial statements, and gains/losses are recognized in profit or loss when the asset is derecognized or impaired. FVOCI – Financial a ssets held to achieve a particular bu siness objective other than short - term trading are designated at FVOCI. Unlike debt instruments designated at FVOCI, there is no recycling of gains or losses through profit and loss. Upon derecognition of the asset, accumulated gains or losses are transfer red from OCI directly to retained earnings. FVPL – Financial assets that do not meet the criteria for amortized cost or FVOCI are measured at FVP L. Financial liabilities are classified as financial liabilities at fair value through profit and loss, amortiz ed cost, or derivatives designated as hedging instruments in an effective hedge. Brookfield Renewable determines the classification of its financial liabilities at initial recognition. Brookfield Renewable’s financial liabilities include accounts payable a nd accrued liabilities, corporate borrowings, non-recourse borrowings, derivative liabilities, and due to related party balances. Financial liabilities are initially measured at fair value, with subsequent measurement determined based on their classificati on as follows: FVPL – Financial liabilities held for trading, such as those acquired for the purpose of selling in the near term, and derivative financial instruments entered into by Brookfield Renewable that do not meet hedge accounting criteria are class ified as fair value through profit and loss. Gains or losses on th ese type s of liabilities are recognized in profit and loss. Amortized cost – All other financial liabilities are classified as amortized cost using the effective interest rate method. Gains and losses are recognized in profit and loss when the liabilities are derecognized as well as through the amortization process. Amortized cost is computed using the effective interest method less any principal repayment or reduction. The calculation takes into account any premium or discount on acquisition and includes transaction costs and fees that are an integral part of the effective interest rate. This category includes trade and other payables, dividends payable, interest-bearing loans and borrowings, and corporate credit facilities. Derivatives and hedge accounting Derivatives are initially recognized at fair value on the date a derivative contract is entered into and are subsequently remeasured to their fair value at the end of each reporting period. The accounting for subsequent changes in fair value depends on whe ther the derivative is designated as a hedging instrument, and if so, the nature of the item being hedged and the type of hedge relationship designated. Brookfield Renewable designates its derivatives as hedges of: Foreign exchange risk associated with t he cash flows of highly probable forecast transactions (cash flow hedges); Foreign exchange risk associated with net investment in foreign operations (net investment hedges); Commodity price risk associated with cash flows of highly probable forecast tra nsactions (cash flow hedges); and Floating interest rate risk associated with payments of debts (cash flow hedges). The fair values of various derivative financial instruments used for hedging purposes and movements in the hedge reserve within equity are shown in Note 5 – Risk Management and Financial Instruments . When a hedging instrument expires, is sold, is terminated, or no longer meets the criteria for hedge accounting, any cumulative deferred gain or loss and deferred costs of hedging in equity at that time remain in equity until the forecasted transaction occurs. When the forecasted transaction is no longer expected to occur, the cumulative gain or loss and deferred costs of hedging are immediately reclassified to profit and loss. If the hedge ratio for risk management purposes is no longer optimal but the risk management objective remains unchanged and the hedge continues to qualify for hedge accounting, the hedge relationship will be rebalanced by adjusting either the volume of the hedging ins trument or the volume of the hedged item so that the hedge ratio aligns with the ratio used for risk management purposes. Any hedge ineffectiveness is calculated and accounted for in profit and loss at the time of the hedge relationship rebalancing. (i) Cash flow hedges that qualify for hedge accounting The effective portion of changes in the fair value of derivatives that are designated and qualify as cash flow hedges is recognized in the cash flow hedge reserve within equity, limited to the cumulati ve change in fair value of the hedged item on a present value basis from the inception of the hedge. The gain or loss relating to the ineffective portion is recognized immediately in profit and loss, within unrealized financial instruments gain (loss) . Ga ins and losses relating to the effective portion of the change in fair value of the entire forward contract are recognized in the cash flow hedge reserve within equity. Amounts accumulated in equity are reclassified in the period when the hedged item affec ts profit and loss. (ii) Net investment hedg es that qualify for hedge accounting Hedges of net investments in foreign operations are accounted for similarly to cash flow hedges. Any gain or loss on the hedging instrument relating to the effective porti on of the hedge is recognized in OCI and accumulated in reserves in equity. The gain or loss relating to the ineffective portion is recognized immediately in profit and loss within foreign exchange and unrealized financial instruments gain (loss) . Gains an d losses accumulated in equity will be reclassified to profit and loss when the foreign operation is partially disposed of or sold. (iii) Hedge ineffectiveness Brookfield Renewable’s hedging policy only allows for the use of derivative instruments that form effective hedge relationships. Hedge effectiveness is determined at the inception of the hedge relationship and through periodic prospective effectiveness assessments to ensure that an economic relationship exists between the hedged item and hedging instrument. Where the critical terms of the hedging instrument match exactly with the terms of the hedged item, a qualitative assessment of effectiveness is performed. For other hedge relationships, the hypothetical derivative method to assess effectivenes s is used.
Hedge accounting	Derivatives and hedge accounting Before January 1, 2018, hedge documentation included identification of the hedging ins trument, the hedged item or transaction, the nature of the risk being hedged and how Brookfield Renewable will assess the effectiveness of changes in the hedging instrument’s fair value in offsetting the exposure to changes in the hedged item’s fair value or cash flows attributable to the hedged risk. Such hedges were expected to be highly effective in achieving offsetting changes in fair value or cash flows and were assessed on an ongoing basis to determine that they had actually been highly effective thro ughout the financial reporting periods for which they were designated. Beginning January 1, 2018, the documentation includes identification of the hedging instrument, the hedged item, the nature of the risk being hedged and how Brookfield Renewable will as sess whether the hedging relationship meets the hedge effectiveness requirements (including the analysis of sources of hedge ineffectiveness and how the hedge ratio is determined). A hedging relationship qualifies for hedge accounting if it meets all of th e following effectiveness requirements: There is ‘an economic relationship’ between the hedged item and the hedging instrument. The effect of credit risk does not ‘dominate the value changes’ that result from that economic relationship. The hedge ratio of the hedging relationship is the same as that resulting from the quantity of the hedged item that Brookfield Renewable actually hedges and the quantity of the hedging instrument that Brookfield Renewable actually uses to hedge that quantity of hedged item. Refer to Note 1(k) – Financial Instruments for details of Brookfield Renewable’s accounting policies for hedge accounting from January 1, 2018 under IFRS 9.
Revenue recognition	The majority of revenue is derived from the sale of power and power related ancillary services both under contract and in the open market, sourced from Brookfield Renewable’s power generating facilities. The obligations are satisfied over time as the customer simultaneously receives and consumes benefits as Brookfield Renewable delivers el ectricity and related products. Revenue is recorded based upon the output delivered and capacity provided at rates specified under either contract terms or prevailing market rates. The revenue reflects the consideration Brookfield Renewable expects to be e ntitled to in exchange for those goods or services. Costs related to the purchases of power or fuel are recorded upon delivery. All other costs are recorded as incurred. Details of the revenue recognized per geographical region are included in Note 6 – Segmented information. Where available, Brookfield Renewable has elected the practical expedient available under IFRS 15 for measuring progress toward complete satisfaction of a performance obligation and for disclosure requirements of remaining performa nce obligations. The practical expedient allows an entity to recognize revenue in the amount to which the entity has the right to invoice such that the entity has a right to the consideration in an amount that corresponds directly with the value to the cus tomer for performance completed to date by the entity. If the consideration in a contract that does not apply the practical expedient available under IFRS 15 for measuring progress toward complete satisfaction of a performance obligation includes a variab le amount, Brookfield Renewable estimates the amount of consideration to which it will be entitled in exchange for transferring the goods to the customer. The variable consideration is estimated at contract inception and constrained until it is highly prob able that a significant revenue reversal in the amount of cumulative revenue recognised will not occur when the associated uncertainty with the variable consideration is subsequently resolved. Brookfield Renewable also sells power and related products unde r bundled arrangements. Energy, capacity and renewable credits within power purchase agreements are considered to be distinct performance obligations. A contract’s transaction price is allocated to each distinct performance obligation and recognized as rev enue when, or as, the performance obligation is satisfied under IFRS 15. Brookfield Renewable views the sale of energy and capacity as a series of distinct goods that is substantially the same and has the same pattern of transfer measured by the output met hod. Brookfield Renewable views renewable credits to be performance obligations satisfied at a point in time. During the year ended December 31, 2018, revenues recognized at a point in time corresponding to t he sale of renewable credits were $ 17 million (2017: $ 18 million). Measurement of satisfaction and transfer of control to the customer of renewable credits in a bundled arrangement coincides with the pattern of revenue recognition of the underlying energy generation. Accordingly, B rookfield Renewable has determined that the pattern of revenue recognition under IFRS 15 is consistent with IAS 18. Revenues recognized that are outside the scope of IFRS 15 include realized gains and losses from derivatives used in the risk management of the Brookfield Renewable's generation activities related to commodity prices. Financial transactions included in revenues for the year ended December 31, 2018 decreased revenues by $ 21 million (2017: $ 16 million). Contract Balances Contract assets – A contract asset is the right to consideration in exchange for goods or services transferred to the customer. If Brookfield Renewable performs by transferring goods or services to a customer before the customer pays consideration or before payment is due, a contract asset is recognized for the earned consideration that is conditional. Trade receivables – A receivable represents Brookfield Renewable’s right to an amount of consideration that is unconditional (i.e., only the passage of time is required before payment of the consideration is due). Contract liabilities – A contract liability is the obligation to transfer goods or services to a customer for which Brookfield Renewable has received consideration (or an amount of consideration is due) from the custo mer. If a customer pays consideration before Brookfield Renewable transfers goods or services to the customer, a contract liability is recognized when the payment is made or the payment is due (whichever is earlier). Contract liabilities are recognized as revenue when Brookfield Renewable performs under the contract.
Income taxes	Current income tax assets and liabilities are measured at the amount expected to be paid to tax authorities, net of recoveries, based on the tax rates and laws enacted or subs tantively enacted at the statement of financial position dates. Current income tax assets and liabilities are included in trade receivables and other current assets and accounts payable and accrued liabilities, respectively. Deferred tax is recognized on taxable temporary differences between the tax bases and the carrying amounts of assets and liabilities. Deferred tax is not recognized if the temporary difference arises from goodwill or from initial recognition (other than in a business combination) of ot her assets and liabilities in a transaction that affects neither taxable profit nor accounting profit. Deferred income tax assets are recognized for all deductible temporary differences, carry forwards of unused tax credits and unused tax losses, to the ex tent that it is probable that deductions, tax credits and tax losses can be utilized. The carrying amount of deferred income tax assets is reviewed at each statement of financial position date and reduced to the extent it is no longer probable that the inc ome tax assets will be recovered. Deferred income tax assets and liabilities are measured at the tax rates that are expected to apply to the year when the assets are realized or the liabilities settled, using the tax rates and laws enacted or substantively enacted at the statement of financial position dates. Current and deferred income taxes relating to items recognized directly in OCI are also recognized directly in OCI.
Business combinations	The acquisition of a business is accounted for using the a cquisition method. The consideration for an acquisition is measured at the aggregate of the fair values, at the date of exchange, of the assets transferred, the liabilities incurred to former owners of the acquired business, and equity instruments issued by the acquirer in exchange for control of the acquired business. The acquired business’ identifiable assets, liabilities and contingent liabilities that meet the conditions for recognition under IFRS 3, Business Combinations , are recognized at their fair values at the acquisition date, except for income taxes which are measured in accordance with IAS 12, Income Taxes , share-based payments which are measured in accordance with IFRS 2, Share-based Payment and non-current assets that are classified as held-fo r-sale which are measured at fair value less costs to sell in accordance with IFRS 5, Non-current Assets Held for Sale and Discontinued Operations . The non-controlling interest in the acquiree is initially measured at the non-controlling interest’s proport ion of the net fair value of the identifiable assets, liabilities and contingent liabilities recognized or when applicable, at the fair value of the shares outstanding. To the extent that the aggregate of the fair value of consideration paid, the amount of any non-controlling interest and the fair value of any previously held interest in the acquiree exceeds the fair value of the net identifiable tangible and intangible assets acquired, goodwill is recognized. To the extent that this difference is negative, the amount is recognized as a gain in income. Goodwill is not amortized and is not deductible for tax purposes. However, after initial recognition, goodwill will be measured at cost less any accumulated impairment losses. An impairment assessment will be performed at least annually, and whenever circumstances such as significant declines in expected revenues, earnings or cash flows indicate that it is more likely than not that goodwill might be impaired. Goodwill impairment charges are not reversible. When a business combination is achieved in stages, previously held interests in the acquired entity are re-measured to fair value at the acquisition date, which is the date control is obtained, and the resulting gain or loss, if any, is recognized in income. A mounts arising from interests in the acquired business prior to the acquisition date that have previously been recognized in OCI are reclassified to income. Upon disposal or loss of control of a subsidiary, the carrying amount of the net assets of the sub sidiary (including any OCI relating to the subsidiary) are derecognized with the difference between any proceeds received and the carrying amount of the net assets recognized as a gain or loss in income. Where applicable, the consideration for the acquis ition includes any asset or liability resulting from a contingent consideration arrangement, measured at its acquisition-date fair value. Subsequent changes in fair values are adjusted against the cost of the acquisition where they qualify as measurement p eriod adjustments. All other subsequent changes in the fair value of contingent consideration classified as liabilities will be recognized in the consolidated statements of income , whereas changes in the fair values of contingent consideration classified w ithin equity are not subsequently re-measured.
Assets held for sale	Non-current assets and disposal groups are classified as held for sale if their carrying amount will be recovered principally through a sale transaction rather than through continuing use. This condition is regarded as met only when the sale is highly probable and th e non-current asset or disposal group is available for immediate sale in its present condition. Management must be committed to the sale, which should be expected to qualify for recognition as a completed sale within one year from the date of classificatio n subject to limited exceptions. When Brookfield Renewable is committed to a sale plan involving loss of control of a subsidiary, all of the assets and liabilities of that subsidiary are classified as held for sale when the criteria described above are met , regardless of whether Brookfield Renewable will retain a non-controlling interest in its former subsidiary after the sale. Non-current assets and disposal groups classified as held for sale are measured at the lower of their previous carrying amount and fair value less costs to sell. Non-current assets classified as held for sale and the assets of a disposal group are presented separately from other assets in the c onsolidated s tatements of f inancial p osition and are classified as current. The liabilities of a disposal group classified as held for sale are presented separately from other liabilities in the c onsolidated s tatements of f inancial p osition. Once classified as held for sale, property, plant and equipment and intangible assets are not depreciated or amortized.
Capitalized costs	Capitalized costs related to CWIP include all eligible expenditures incurred in connection with the development and construction of the power generating asset. The expenditures consist of cost of ma terials, direct labor and any other costs directly attributable to bringing the asset to a working condition for its intended use, and the costs of dismantling and removing the items and restoring the site on which they are located. Interest and borrowing costs are capitalized when activities that are necessary to prepare the asset for its intended use or sale are in progress, expenditures for the asset have been incurred and funds have been used or borrowed to fund the construction or development. Capitali zation of costs ceases when the asset is ready for its intended use.
Pension and employees future benefits	Pension and employee future benefits are recognized in the consolidated financial statements in respect of employees of the operating enti ties within Brookfield Renewable. The costs of retirement benefits for defined benefit plans and post-employment benefits are recognized as the benefits are earned by employees. The project unit credit method, using the length of service and management’s b est estimate assumptions, is used to value its pension and other retirement benefits. All actuarial gains and losses are recognized immediately through OCI in order for the net pension asset or liability recognized in the consolidated statements of financi al position to reflect the full value of the plan deficit or surplus. Net interest is calculated by applying the discount rate to the net defined benefit asset or liability. Changes in the net defined benefit obligation related to service costs (comprising of current service costs, past services costs, gains and losses on curtailments and non-routine settlements), and net interest expense or income are recognized in the consolidated statements of income. Re-measurements, comprising of actuarial gains or l osses, the effect of the asset ceiling, and the return on plan assets (excluding net interest), are recognized immediately in the consolidated statements of financial position with a corresponding debit or credit to OCI in the period in which they occur. R e- measurements are not reclassified to profit or loss in subsequent periods. For defined contribution plans, amounts are expensed based on employee entitlement.
Decommisioning, restoration and environmental liabilities	Legal and constructive obligations associated with the retirement of property, plant and equipment are recorded as liabilities when those obligations are incurred and are measured at the present value of the expected costs to settle the liability, using a discount rate that reflects the current market assessments of the time value of money and the risks specific to the liability . The liability is accreted up to the date the liability will be incurred with a corresponding charge to operating expenses. The ca rrying amount of decommissioning, restoration and environmental liabilities is reviewed annually with changes in the estimates of timing or amount of cash flows added to or deducted from the cost of the related asset.
Interest and borrowing costs	Interest and borrowing costs are capitalized when such costs are directly attributable to the acquisition, construction or production of a qualifying asset. A qualifying asset is an asset that takes a substantial period of time to prepare for its intended use.
Provisions	A provision is a liability of uncertain timing or amount. A provision is recognized if Brookfield Renewable has a present legal or constructive obligation as a result of past events, it is probable that an outflow of resources will be required to settle the obligation and the amount can be reliably estimated. Provisions are not recognized for future operating losses. The provision is measured at the present value of the best estimate of the expenditures expected to be required to se ttle the obligation using a discount rate that reflects the current market assessments of the time value of money and the risks specific to the obligation. Provisions are re-measured at each statement of financial position date using the current discount r ate. The increase in the provision due to the passage of time is recognized as interest expense.
Interest income	Interest income is earned with the passage of time and is recorded on an accrual basis.
Government grants	Brookfield Renewa ble becomes eligible for government grants by constructing or purchasing renewable power generating assets, and by bringing those assets to commercial operation, coupled with a successful application to the applicable program or agency. The assessment of w hether or not a project has complied with the conditions and that there is reasonable assurance the grants will be received will be undertaken on a case by case basis. Brookfield Renewable reduces the cost of the asset by the amount of the grant. The gran t amounts are recognized in income on a systematic basis as a reduction of depreciation over the periods, and in the proportions, in which depreciation on those assets is charged. With respect to grants related to income, the government assistance (in the form of the difference between market price and guaranteed fixed price) typically becomes payable once electricity is produced and delivered to the relevant grid. It is at this point that the receipt of the grant becomes reasonably assured, and therefore t he grant is recognized as revenue in the month that delivery of the electricity occurs.
Critical estimates and judgements in applying accounting policies	(q) Critical estimates Brookfield Renewable makes estimates and assumptions that affect the carrying value of assets and liabilities, disclosure of contingent assets a nd liabilities and the reported amount of income and OCI for the year. Actual results could differ from these estimates. The estimates and assumptions that are critical to the determination of the amounts reported in the consolidated financial statements r elate to the following: (i) Property, plant and equipment The fair value of Brookfield Renewable’s property, plant and equipment is calculated using estimates and assumptions about future electricity prices from renewable sources, anticipated long-ter m average generation, estimated operating and capital expenditures, future inflation rates and discount rates, as described in Note 12 - Property, plant and equipment, at fair value. Judgment is involved in determining the appropriate estimates and assu mptions in the valuation of Brookfield Renewable’s property, plant and equipment. See Note 1(r)(iii) - Critical judgments in applying accounting policies - Property, plant and equipment for further details. Estimates of useful lives and residual values ar e used in determining depreciation and amortization. To ensure the accuracy of useful lives and residual values, these estimates are reviewed on an annual basis. (ii) Financial instruments Brookfield Renewable makes estimates and assumptions that affe ct the carrying value of its financial instruments, including estimates and assumptions about future electricity prices, long-term average generation, capacity prices, discount rates and the timing of energy delivery. The fair value of interest rate swaps is the estimated amount that another party would receive or pay to terminate the swap agreements at the reporting date, taking into account current market interest rates. This valuation technique approximates the net present value of future cash flows. See Note 5 - Risk management and financial instruments for more details. (iii) Deferred income taxes The consolidated financial statements include estimates and assumptions for determinin g the future tax rates applicable to subsidiaries and identifying the temporary differences that relate to each subsidiary. Deferred income tax assets and liabilities are measured at the tax rates that are expected to apply during the year when the assets are realized or the liabilities settled, using the tax rates and laws enacted or substantively enacted at the consolidated statement of financial position dates. Operating plans and forecasts are used to estimate when the temporary difference will reverse. (r) Critical judgments in applying accounting policies The following are the critical judgments that have been made in applying the accounting policies used in the consolidated financial statements and that have the most significant effect on the amounts in the consolidated financial statements: (i) Preparation of consolidated financial statements These consolidated financial statements present the financial position, results of operations and cash flows of Brookfield Renewable. Brookfield Renewable e xercises judgment in determining whether non-wholly owned subsidiaries are controlled by Brookfield Renewable. Brookfield Renewable’s judgement included the determination of (i) how the relevant activities of the subsidiary are directed; (ii) whether the r ights of shareholdings are substantive or protective in nature; and (iii) Brookfield Renewable’s ability to influence the returns of the subsidiary. (ii) Common control transactions Common control business combinations specifically fall outside of sco pe of IFRS 3 and as such management has used its judgment to determine an appropriate policy to account for these transactions, considering other relevant accounting guidance that is within the framework of principles in IFRS and that reflects the economic reality of the transactions, in accordance with IAS 8, Accounting Policies, Changes in Accounting Estimates and Errors . As a result, the consolidated financial statements account for assets and liabilities acquired at the previous carrying value on the pr edecessor’s financial statements. Differences between the consideration given and the assets and liabilities received are recorded directly to equity. (iii) Property, plant and equipment The accounting policy relating to Brookfield Renewable’s propert y, plant and equipment is described in Note 1(h) - Property, plant and equipment and revaluation method. In applying this policy, judgment is used in determining whether certain costs are additions to the carrying amount of the property, plant and equipmen t as opposed to repairs and maintenance. If an asset has been developed, judgment is required to identify the point at which the asset is capable of being used as intended and to identify the directly attributable costs to be included in the carrying value of the development asset. The useful lives of property, plant and equipment are determined by independent engineers periodically with an annual review by management. Annually, Brookfield Renewable determines the fair value of its property, plant and equipment using a methodology that it has judged to be reasonable. The methodology is generally a 20-year discounted cash flow model. Twenty years is the period considered reasonable as Brookfield Renewable has 20-year capital plans and it believes a reaso nable third party would be indifferent between extending the cash flows further in the model versus using a discounted terminal value. The valuation model incorporates future cash flows from long-term power purchase agreements that are in place where it i s determined that the power purchase agreements are linked specifically to the related power generating assets. With respect to estimated future generation that does not incorporate long-term power purchase agreement pricing, the cash flow model uses estim ates of future electricity prices using broker quotes from independent sources for the years in which there is a liquid market. The valuation of power generating assets not linked to long-term power purchase agreements also requires the development of a lo ng-term estimate of future electricity prices. In this regard the valuation model uses a discount to the all-in cost of construction with a reasonable return, to secure energy from new renewable on-shore wind development resources as the benchmark that wil l establish the market price for electricity for renewable resources. Brookfield Renewable’s long-term view is anchored to the cost of securing new energy from renewable sources to meet future demand growth by the year 2025 in North America and Colombia, 2 023 in Europe, and 202 2 in Brazil. The year of new entry is viewed as the point when generators must build additional capacity to maintain system reliability and provide an adequate level of reserve generation with the retirement of older coal fired plant s and rising environmental compliance costs in North America and Europe, and overall increasing demand in Colombia and Brazil. For the North American and European businesses, Brookfield Renewable has estimated a discount to these new-build wind prices to d etermine renewable electricity prices for hydroelectric and wind facilities. In Brazil and Colombia, the estimate of future electricity prices is based on a similar approach as applied in North America using a forecast of the all-in cost of development. T erminal values are included in the valuation of hydroelectric assets in North America and Colombia. For the hydroelectric assets in Brazil, cash flows have been included based on the duration of the authorization or useful life of a concession asset with c onsideration of a one-time 30-year renewal on our qualifying hydroelectric assets. Discount rates are determined each year by considering the current interest rates, average market cost of capital as well as the price risk and the geographical location of the operational facilities as judged by management. Inflation rates are also determined by considering the current inflation rates and the expectations of future rates by economists. Operating costs are based on long-term budgets escalated for inflation. Each operational facility has a 20-year capital plan that it follows to ensure the maximum life of its assets is achieved. Foreign exchange rates are forecasted by using the spot rates and the available forward rates, extrapolated beyond the period availab le. The inputs described above to the discounted cash flow model require management to consider facts, trends and plans in making its judgments as to what derives a reasonable fair value of its property, plant and equipment. (iv) Financial instruments The accounting policy relating to Brookfield Renewable’s financial instruments is described in Note 1(k) - Financial instruments. In applying the policy, judgments are made in applying the criteria set out in IFRS 9 and IAS 39, to record financial instrume nts at fair value through profit and loss, fair value through other comprehensive income and the assessments of the effectiveness of hedging relationships. (v) Deferred income taxes The accounting policy relating to Brookfield Renewable’s income taxes is described in Note 1(m) - Income taxes. In applying this policy, judgments are made in determining the probability of whether deductions, tax credits and tax losses can be utilized.
IFRS 9 [Member]
Disclosure of expected impact of initial application of new standards or interpretations [line items]
Future changes in accounting policies	(ii) IFRS 9, Financial instruments (“IFRS 9”) Brookfield Renewable adopted IFRS 9, as issued by the IASB in 2014, which pr ovides more reliable and relevant information for users to assess the amounts, timing and uncertainty of future cash flows. The new accounting policy was applied prospectively, with an initial application date of January 1, 2018. Brookfield Renewable has n ot restated the comparative information, which continues to be reported under IAS 39, Financial Instruments Recognition and Measurement (“IAS 39”). The adoption of IFRS 9 did not result in any material transition adjustments being recognized as at January 1, 2018 IFRS 9 replaces certain provisions of IAS 39 that relate to the recognition, classification and measurement of financial assets and financial liabilities; derecognition of financial instruments; impairment of financial assets; and hedge accounting. IFRS 9 also significantly amends other standards dealing with financial instruments such as IFRS 7, Financial Instruments: Disclosures .
IFRS 15 [Member]
Disclosure of expected impact of initial application of new standards or interpretations [line items]
Future changes in accounting policies	(i) IFRS 15, Revenue from contracts with customers (“IFRS 15”) On January 1, 2018 Brookfield Renewable adopted IFRS 15 using the modified retrospective method applied to those contracts which were not completed as of January 1, 2018. IFRS 15 supersedes IAS 11 Construction Contracts, IAS 18 Revenue and related interpre tations and it applies, with limited exceptions, to all revenue arising from contracts with its customers. IFRS 15 requires that revenue be recognized at an amount that reflects the consideration to which an entity expects to be entitled in exchange for tr ansferring goods or services to a customer using a five-step model , which requires the identification of a contract with a customer, the identification of performance obligations within the contract, determination of the transaction price, the allocation o f the transaction price to the performance obligations and the recognition of revenue when performance obligations have been satisfied. IFRS 15 requires entities to exercise judgement, taking into consideration all the relevant facts and circumstances whe n applying each step of the model to contracts with their customers. The standard also specifies the accounting for the incremental costs of obtaining a contract and the costs directly related to fulfilling a contract. The pattern and timing of revenue rec ognition under the new standard is consistent with prior practice. There were no adjustments recognized on the adoption of IFRS 15.

BASIS OF PREPARATION AND SIGN_3

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Financial instruments and new classification categories under IFRS 9	Classification category IAS 39 IFRS 9 Carrying amount IAS 39 and IFRS 9 ($ Millions) Financial assets Cash and cash equivalents FVPL Amortized cost 799 Restricted cash (1) FVPL Amortized cost 284 Trade receivables and other current assets Loans and receivables Amortized cost 554 Financial instrument assets - investments in equity securities (1)(2) Available-for-sale FVOCI 159 Financial instrument assets - derivative financial instruments (1)(3) FVPL FVPL 20 Financial instrument assets - derivative financial instruments designated as hedges (1)(3) Financial instruments designated as hedges Financial instruments designated as hedges 6 Due from related parties Loans and receivables Amortized cost 60 Financial liabilities Accounts payable and accrued liabilities Other liabilities Amortized cost 542 Financial instrument liabilities - derivative financial instruments (1)(3) FVPL FVPL 145 Financial instrument liabilities - derivative financial instruments designated as hedges (1)(3) Financial instruments designated as hedges Financial instruments designated as hedges 125 Due to related parties Other liabilities Amortized cost 112 Corporate borrowings (1) Other liabilities Amortized cost 2,552 Non-recourse borrowings (1) Other liabilities Amortized cost 9,214 Includes both current and non-current portions. Investments in equity securities were originally referred to as available-for-sale securities in the 2017 annual consolidated financial statements. Derivative financial instruments comprise of energy derivative contracts, interest rate swaps and foreign exchange swaps.
Depreciation on power generating assets is calculated on a straight-line basis over the estimated service lives of the assets, which are as follows	Estimated service lives Dams Up to 115 years Penstocks Up to 60 years Powerhouses Up to 115 years Hydroelectric generating units Up to 115 years Wind generating units Up to 30 years Solar generating units Up to 30 years Gas-fired cogenerating (“Cogeneration”) units Up to 40 years Other assets Up to 60 years

PRINCIPAL SUBSIDIARIES (Tables)

PRINCIPAL SUBSIDIARIES (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following table lists the subsidiaries of Brookfield Renewable which, in the opinion of management, significantly affects its financial position and results of operations as at December 31:	Jurisdiction of Percentage of Incorporation voting securities or Organization owned or controlled (%) Alta Wind VIII LLC (1) Delaware 100 BIF II Safe Harbor Holdings LLC (1) Delaware 100 BIF III Holtwood LLC (1) Delaware 100 BRE GLBL Holdings L.P. (1) Bermuda 100 BRI Green Energy Limited (1) Republic of Ireland 100 Brookfield BRP Canada Corp. Alberta 100 Brookfield Energia Comercializadora Ltda Brazil 100 Brookfield Power US Holding America Co. Delaware 100 Brookfield Renewable UK Hydro Limited England and Wales 100 Brookfield Smoky Mountain Hydropower LLC (1) Delaware 100 Brookfield White Pine Hydro LLC (1) Delaware 100 Catalyst Old River Hydroelectric Limited Partnership (2) Louisiana 75 Erie Boulevard Hydropower, L.P. Delaware 100 Great Lakes Hydro America, LLC Delaware 100 Great Lakes Power Limited Ontario 75 Hawks Nest Hydro LLC Delaware 100 Isagen S.A. E.S.P. (1) Colombia 99.5 Kwagis Power Limited Partnership British Columbia 75 Lièvre Power L.P. Québec 100 Mississagi Power Trust Québec 100 Orion Canadian Holdings 1 AIV L.P. Ontario 100 Powell River Energy Inc. Canada 100 Rumford Falls Hydro LLC Delaware 100 Safe Harbor Water Power Corporation (1) Pennsylvania 100 Tangará Energia S.A. (1) Brazil - São Paulo 100 Windstar Energy, LLC California 100 2016 Comber Wind Limited Partnership Ontario 100 Voting control held through voting agreements with Brookfield. Non-voting economic interest held through preferred shares and secured notes.

ACQUISITIONS (Tables)

ACQUISITIONS (Tables)	12 Months Ended
	Dec. 31, 2018
Acqusitions Completed In 2018
Acqusition Tables
Final purchase price allocations, at fair values, with respect to the acquisitions are as follows:	Northern Ireland (MILLIONS) Note Biotherm Wind Total Cash and cash equivalents $ 12 $ 1 $ 13 Trade receivables and other current assets 7 - 7 Property, plant and equipment, at fair value 158 53 211 Current liabilities (3) (4) (7) Current portion of non-recourse borrowings (3) - (3) Financial instruments (2) - (2) Non-recourse borrowings (69) (18) (87) Deferred income tax liabilities (35) (4) (39) Non-controlling interests (21) - (21) Fair value of net assets acquired 44 28 72 Goodwill 17 27 - 27 Purchase price $ 71 $ 28 $ 99
Acqusitions Completed In 2017
Acqusition Tables
Final purchase price allocations, at fair values, with respect to the acquisitions are as follows:	TerraForm European (MILLIONS) Global Wind Total Cash and cash equivalents $ 611 $ - $ 611 Restricted cash 90 - 90 Trade receivables and other current assets 62 1 63 Financial instruments 20 - 20 Property, plant and equipment, at fair value 1,208 37 1,245 Deferred tax assets 18 - 18 Other long-term assets 94 - 94 Current liabilities (73) (4) (77) Current portion of non-recourse borrowings (1,183) - (1,183) Financial instruments (15) - (15) Non-recourse borrowings (5) - (5) Deferred income tax liabilities (15) (2) (17) Other long-term liabilities (54) - (54) Non-controlling interests (1) - (1) Fair value of net assets acquired $ 757 $ 32 $ 789
Acqusitions Completed In 2016
Acqusition Tables
Final purchase price allocations, at fair values, with respect to the acquisitions are as follows:	(MILLIONS) Colombia Brazil Pennsylvania Ireland Total Cash and cash equivalents $ 113 $ 4 $ - $ - $ 117 Trade receivables and other current assets 174 2 1 - 177 Property, plant and equipment, at fair value 4,772 100 859 10 5,741 Other long-term assets 15 - - - 15 Current liabilities (463) (3) (1) - (467) Non-recourse borrowings (899) - - - (899) Deferred income tax liabilities (1,019) - - (1) (1,020) Other long-term liabilities (149) - - - (149) Non-controlling interests (1,417) - - - (1,417) Fair value of net assets acquired 1,127 103 859 9 2,098 Goodwill 799 - - - 799 Purchase price $ 1,926 $ 103 $ 859 $ 9 $ 2,897

ASSETS HELD FOR SALE (Tables)

ASSETS HELD FOR SALE (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following is a summary of the major items of assets and liabilities classified as held for sale	(MILLIONS) Total Assets Cash and cash equivalents $ 8 Restricted cash 47 Trade receivables and other current assets 28 Property, plant and equipment, at fair value 749 Goodwill 22 Other long-term assets 66 Assets held for sale $ 920 Liabilities Current liabilities $ 23 Non-recourse borrowings 360 Other long-term liabilities 150 Liabilities directly associated with assets held for sale $ 533

RISK MANAGEMENT AND FINANCIAL_2

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2018
Disclosure of risk management strategy related to hedge accounting [line items]
The table below classifies the cash obligations related to Brookfield Renewables liabilities into relevant maturity groupings based on the remaining period from the statement of financial position dates to the contractual maturity date	AS AT DECEMBER 31, 2018 (MILLIONS) < 1 year 2-5 years > 5 years Total Accounts payable and accrued liabilities $ 533 $ - $ - $ 533 Financial instrument liabilities (1) 27 57 54 138 Due to related parties 101 - - 101 Other long-term liabilities - concession payments 1 4 10 15 Corporate borrowings (1) 6 1,344 990 2,340 Non-recourse borrowings (1) 489 2,806 5,164 8,459 Interest payable on borrowings (2) 577 1,906 1,684 4,167 Total $ 1,734 $ 6,117 $ 7,902 $ 15,753 AS AT DECEMBER 31, 2017 (MILLIONS) < 1 year 2-5 years > 5 years Total Accounts payable and accrued liabilities $ 542 $ - $ - $ 542 Financial instrument liabilities (1) 184 62 24 270 Due to related parties 112 - - 112 Other long-term liabilities - concession payments 1 3 10 14 Corporate borrowings (1) 159 1,563 835 2,557 Non-recourse borrowings (1) 1,517 3,024 4,744 9,285 Interest payable on borrowings (2) 634 1,924 1,697 4,255 Total $ 3,149 $ 6,576 $ 7,310 $ 17,035 Includes both the current and long-term amounts. Represents aggregate interest payable expected to be paid over the entire term of the obligations, if held to maturity. Variable rate interest payments have been calculations based on estimated interest rates.
The following table presents Brookfield Renewables assets and liabilities measured and disclosed at fair value classified by the fair value hierarchy as at December 31:	(MILLIONS) Level 1 Level 2 Level 3 2018 2017 Assets measured at fair value: Cash and cash equivalents $ 173 $ - $ - $ 173 $ 799 Restricted cash (1) 181 - - 181 284 Financial instrument assets (2)(3) Energy derivative contracts - 3 - 3 - Interest rate swaps - 9 - 9 6 Foreign exchange swaps - 55 - 55 20 Investments in equity securities (2) 60 57 - 117 159 Property, plant and equipment - - 29,025 29,025 27,096 Liabilities measured at fair value: Financial instrument liabilities (3) Energy derivative contracts - (22) - (22) (19) Interest rate swaps - (116) - (116) (155) Foreign exchange swaps - - - - (96) Contingent consideration (4) - - (3) (3) (18) Assets for which fair value is disclosed: Equity-accounted investments (5) 703 - - 703 278 Liabilities for which fair value is disclosed: Corporate borrowings (1,640) (727) - (2,367) (2,641) Non-recourse borrowings (370) (8,326) - (8,696) (9,838) Total $ (893) $ (9,067) $ 29,022 $ 19,062 $ 15,875 Includes both the current amount and long-term amount included in Other long-term assets. Amounts in Level 2 include Brookfield Infrastructure Debt Fund holdings. Includes both current and long-term amounts. Amount relates to business combinations with obligations lapsing in 2021 and 2024. The fair value corresponds to Brookfield Renewable’s investment in publicly-quoted common shares of TerraForm Power, Inc .
The aggregate amount of Brookfield Renewables net financial instrument positions as at December 31 are as follows:	2018 2017 Net Assets Net Assets (MILLIONS) Assets Liabilities (Liabilities) (Liabilities) Energy derivative contracts $ 3 $ 22 $ (19) $ (19) Interest rate swaps 9 116 (107) (149) Foreign exchange swaps 55 - 55 (76) Investments in equity securities 117 - 117 159 Total 184 138 46 (85) Less: current portion 60 27 33 (112) Long-term portion $ 124 $ 111 $ 13 $ 27
The following table presents the change in Brookfield Renewables total net financial instrument asset position as at and for the year ended December 31	(MILLIONS) Note 2018 2017 2016 Balance, beginning of year $ (85) $ (28) $ (145) Increases (decreases) in the net financial instrument liability position: Unrealized (loss) gain through OCI on investments in equity securities (a) (16) (20) 52 Unrealized (loss) through income on energy derivative contracts (b) (3) (5) - Unrealized (loss) through OCI on energy derivative contracts (b) - (17) (28) Unrealized gain (loss) through income on interest rate swaps (c) 17 1 (7) Unrealized gain (loss) through OCI on interest rate swaps (c) 14 18 (1) Unrealized gain (loss) through income on foreign exchange swaps (d) 76 (29) 3 Unrealized gain (loss) through OCI on foreign exchange swaps (d) 87 (94) (61) Acquisitions, settlements and other (44) 89 159 Balance, end of year $ 46 $ (85) $ (28) Financial instrument assets designated at fair value through OCI Investments in equity securities (a) 117 159 136 Derivative assets not designated as hedging instruments: Energy derivative contracts (b) $ 3 $ - $ 3 Interest rate swaps (c) - 1 1 Foreign exchange swaps (d) 32 19 10 Net positions $ 35 $ 20 $ 14 Derivative assets designated as hedging instruments: Energy derivative contracts (b) $ - $ - $ 5 Interest rate swaps (c) 9 5 6 Foreign exchange swaps (d) 23 1 39 Net positions $ 32 $ 6 $ 50 Derivative liabilities not designated as hedging instruments: Energy derivative contracts (b) $ (7) $ (5) $ (3) Interest rate swaps (c) (82) (107) (2) Foreign exchange swaps (d) - (33) (6) Net positions $ (89) $ (145) $ (11) Derivative liabilities designated as hedging instruments: Energy derivative contracts (b) $ (15) $ (14) $ (2) Interest rate swaps (c) (34) (48) (176) Foreign exchange swaps (d) - (63) (39) Net positions $ (49) $ (125) $ (217) Total financial instruments, net $ 46 $ (85) $ (28)
Credit risk [member]
Disclosure of risk management strategy related to hedge accounting [line items]
The sensitivity analysis discussed below reflect the risks associated with instruments that Brookfield Renewable considers are market sensitive and the potential loss resulting from one or more selected hypothetical changes	(MILLIONS) 2018 2017 Trade receivables and other short-term receivables 493 442 Due from related parties 65 60 Other long-term assets 402 - $ 960 $ 502
Market risk [Member]
Disclosure of risk management strategy related to hedge accounting [line items]
The sensitivity analysis discussed below reflect the risks associated with instruments that Brookfield Renewable considers are market sensitive and the potential loss resulting from one or more selected hypothetical changes	Effect on net income (1) Effect on OCI (1) (MILLIONS) 2018 2017 2016 2018 2017 2016 5% increase $ 30 $ 4 $ 1 $ 44 $ 79 $ 51 5% decrease (30) (4) (1) (44) (79) (51) Amounts represent the potential annual net pretax impact.
Interest rate risk [Member]
Disclosure of risk management strategy related to hedge accounting [line items]
The sensitivity analysis discussed below reflect the risks associated with instruments that Brookfield Renewable considers are market sensitive and the potential loss resulting from one or more selected hypothetical changes	Effect on net income (1) Effect on OCI (1) (MILLIONS) 2018 2017 2016 2018 2017 2016 1% increase $ (10) $ 17 $ (17) $ 42 $ 54 $ 115 1% decrease 11 (17) 17 (42) (54) (115) Amounts represent the potential annual net pretax impact.
Commodity price risk [member]
Disclosure of risk management strategy related to hedge accounting [line items]
The sensitivity analysis discussed below reflect the risks associated with instruments that Brookfield Renewable considers are market sensitive and the potential loss resulting from one or more selected hypothetical changes	Effect on net income (1) Effect on OCI (1) (MILLIONS) 2018 2017 2016 2018 2017 2016 5% increase $ (3) $ (3) $ (1) $ (10) $ (4) $ (7) 5% decrease 3 3 1 10 4 7 Amounts represent the potential annual net pretax impact.
Energy Derivative Contracts
Disclosure of risk management strategy related to hedge accounting [line items]
Derivative contracts designated as hedging instruments	Dec 31 Energy derivative contracts 2018 Carrying amount (asset/(liability)) (15) Notional amount - millions of U.S. dollars 188 Notional amount - GWh 5,024 Weighted average hedged rate for the year ($/MWh) 37 Maturity dates Jan 2019 - Dec 2020 Hedge ratio 1:1 Change in discounted spot value of outstanding hedging instruments (8) Change in value of hedged item used to determine hedge effectiveness 9
Interest rate hedges
Disclosure of risk management strategy related to hedge accounting [line items]
Derivative contracts designated as hedging instruments	Dec 31 Interest rate hedges 2018 Carrying amount (asset/(liability)) (25) Notional amount - $ 178 Notional amount - C$ (1) 151 Notional amount - € (1) 377 Notional amount - £ (1) 99 Notional amount - COP (1) 256 Maturity dates Aug 2019 - Sep 2036 Hedge ratio 1:1 Change in discounted spot value of outstanding hedging instruments 8 Change in value of hedged item used to determine hedge effectiveness (2)
Foreign exchange swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Derivative contracts designated as hedging instruments	Dec 31 Foreign exchange swaps 2018 Carrying amount (asset/(liability)) 23 Notional amount for hedges of the Canadian dollar (1) 419 Notional amount for hedges of the Euro (1) 221 Notional amount for hedges of the British pounds sterling (1) 247 Maturity date Jan 2019 - Dec 2019 Hedge ratio 1:1 Weighted average hedged rate for the year: C$/$ foreign exchange forward contracts 1.34 €/$ foreign exchange forward contracts 0.82 £/$ foreign exchange forward contracts 0.76
Investments in equity securities
Disclosure of risk management strategy related to hedge accounting [line items]
Derivative contracts designated as hedging instruments	Investments Foreign Cash flow in equity currency (MILLIONS) hedges securities translation Balance, as at December 31, 2017 $ (29) $ 15 $ (378) Effective portion of changes in fair value arising from: Energy derivative contracts (1) - - Interest rate swaps 1 - - Foreign exchange swaps - - 42 Amount reclassified to profit or loss 7 - - Foreign currency revaluation of designated borrowings - - 87 Foreign currency revaluation of net foreign operations - - (324) Valuation of investments in equity securities designated FVOCI - (8) - Tax effect (2) - (10) Other (10) (3) (69) Balance, as at December 31, 2018 $ (34) $ 4 $ (652)

SEGMENTED INFORMATION (Tables)

SEGMENTED INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following table reconciles Adjusted EBITDA and Funds From Operations, presented in the above tables, to net income as presented in the consolidated statements of income (loss), for the year ended December 31:	Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Solar Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Brazil Colombia America Europe Brazil Asia Other investments interests financials (1) Revenues 893 244 216 219 73 42 12 146 85 - 1,930 (286) 1,338 2,982 Other income 12 5 4 2 11 - - 5 - 7 46 (7) 11 50 Direct operating costs (286) (76) (94) (64) (27) (9) (4) (34) (36) (23) (653) 86 (469) (1,036) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - - - 207 20 227 Adjusted EBITDA 619 173 126 157 57 33 8 117 49 (16) 1,323 - 900 - Management service costs - - - - - - - - - (80) (80) - - (80) Interest expense - borrowings (172) (22) (38) (63) (17) (9) (4) (45) (17) (99) (486) 82 (301) (705) Current income taxes (4) (9) (2) (1) (2) - 1 - - - (17) 3 (16) (30) Distributions attributable to Preferred limited partners equity - - - - - - - - - (38) (38) - - (38) Preferred equity - - - - - - - - - (26) (26) - - (26) Share of interest and cash taxes from equity accounted investments - - - - - - - - - - - (85) (12) (97) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - - - (571) (571) Funds From Operations 443 142 86 93 38 24 5 72 32 (259) 676 - - - Depreciation (231) (136) (18) (122) (43) (13) (2) (40) (23) (2) (630) 96 (285) (819) Foreign exchange and unrealized financial instrument loss (1) (1) 7 2 9 (10) 3 (9) (2) - (2) (3) (29) (34) Deferred income tax recovery (1) 1 18 20 2 - - 21 - 24 85 (50) 54 89 Other (21) (3) (6) (11) (1) - (2) (11) (9) (23) (87) 19 (14) (82) Share of earnings from equity accounted investments - - - - - - - - - - - (62) - (62) Net income attributable to non-controlling interests - - - - - - - - - - - - 274 274 Net income (loss) attributable to Unitholders (2) 189 3 87 (18) 5 1 4 33 (2) (260) 42 - - 42 Share of earnings from equity-accounted investments of $68 million is comprised of amounts found on the share of Adjusted EBITDA, share of interest and cash taxes and share of earnings lines. Net income attributable to participating non-contr olling interests – in operating subsidiaries of $ 297 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests. Net income (loss) attribu table to Unitholders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limited partners equity and preferred equity. Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Solar Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Brazil Colombia America Europe Brazil Other investments interests financials (1) Revenues 945 243 191 161 46 26 8 59 - 1,679 (74) 1,020 2,625 Other income 1 12 2 - - - - 6 19 40 (11) 18 47 Direct operating costs (281) (77) (94) (42) (20) (4) (2) (32) (25) (577) 28 (429) (978) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 57 - 57 Adjusted EBITDA 665 178 99 119 26 22 6 33 (6) 1,142 - 609 - Management service costs - - - - - - - - (82) (82) - - (82) Interest expense - borrowings (180) (18) (42) (45) (10) (6) (3) (14) (89) (407) 21 (246) (632) Current income taxes 1 (12) (5) - (1) - (1) - - (18) 1 (22) (39) Distributions attributable to Preferred limited partners equity - - - - - - - - (28) (28) - - (28) Preferred equity - - - - - - - - (26) (26) - - (26) Share of interest and cash taxes from equity accounted investments - - - - - - - - - (22) - (22) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - (341) (341) Funds From Operations 486 148 52 74 15 16 2 19 (231) 581 - - - Depreciation (220) (142) (26) (90) (25) (7) (4) (25) - (539) 22 (265) (782) Foreign exchange and unrealized financial instrument loss (12) (3) (3) 1 (14) - (1) - (15) (47) 2 (1) (46) Deferred income tax expense (67) 2 (10) 28 5 - 1 - 16 (25) (3) (21) (49) Other (17) (8) 6 (4) 4 2 (3) - (6) (26) 12 (1) (15) Share of earnings from equity accounted investments - - - - - - - - - - (33) - (33) Net income attributable to non-controlling interests - - - - - - - - - - - 288 288 Net income (loss) attributable to Unitholders (2) 170 (3) 19 9 (15) 11 (5) (6) (236) (56) - - (56) Share of earnings from equity-accounted investments of $2 million is comprised of amounts found on the share of Adjusted EBITDA, share of interest and cash taxes and share of earnings lines. Net income attributable to participating non-controlling interests – in operating subsidiaries of $ 53 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests. Net income (los s) attributable to Unitholders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limite d partners equity and preferred equity. Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Brazil Colombia America Europe Brazil Other investments interests financials (1) Revenues 819 187 192 151 56 17 58 1 1,481 (37) 1,008 2,452 Other income 24 13 3 - - - (1) 8 47 - 17 64 Direct operating costs (295) (70) (107) (36) (24) (4) (26) (24) (586) 16 (468) (1,038) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 21 - 21 Adjusted EBITDA 548 130 88 115 32 13 31 (15) 942 - 557 - Management service costs - - - - - - - (62) (62) - - (62) Interest expense - borrowings (177) (24) (36) (41) (14) (7) (12) (91) (402) 12 (216) (606) Current income taxes (4) (9) (6) - - - - - (19) - (25) (44) Distributions attributable to Preferred limited partners equity - - - - - - - (15) (15) - - (15) Preferred equity - - - - - - - (25) (25) - - (25) Share of interest and cash taxes from equity accounted investments - - - - - - - - - (12) - (12) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - (316) (316) Funds From Operations 367 97 46 74 18 6 19 (208) 419 - - - Depreciation (244) (125) (31) (80) (38) (4) (18) - (540) 11 (252) (781) Foreign exchange and unrealized financial instrument loss 1 - 1 - - - 2 - 4 - - 4 Deferred income tax expense (recovery) 31 7 6 49 6 - - (21) 78 - 19 97 Other (27) (5) 3 4 6 (1) (2) (4) (26) (2) (18) (46) Share of earnings from equity accounted investments - - - - - - - - - (9) - (9) Net income attributable to non-controlling interests - - - - - - - - - - 251 251 Net income (loss) attributable to Unitholders (2) 128 (26) 25 47 (8) 1 1 (233) (65) - - (65) Share of earnings from equity-accounted investments of $nil is comprised of amounts found on the share of Adjusted EBITDA, share of interest and cash taxes and share of earnings lines. Net income attributable to participating non-controlling interests – in operating subsidiaries of $ 65 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests. Net income (loss) attributable to Unith olders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limited partners equity and pr eferred equity.
The following table presents information on a segmented basis about certain items in Brookfield Renewables statement of financial position:	Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Solar Storage Corporate Total equity to non- As per North North and accounted controlling IFRS (MILLIONS) America Colombia Brazil America Europe Brazil Asia Other investments interests financials As at December 31, 2018: Cash and cash equivalents $ 6 $ 7 $ 37 $ 30 $ 29 $ 5 $ 2 $ 41 $ 9 $ 3 $ 169 $ (81) $ 85 $ 173 Property, plant and equipment, at fair value 11,498 1,609 1,907 2,480 819 348 36 1,354 686 (9) 20,728 (3,529) 11,826 29,025 Total assets 12,125 1,868 2,105 2,554 939 379 56 1,650 746 161 22,583 (2,483) 14,003 34,103 Total borrowings 2,995 419 198 1,204 463 75 31 1,021 249 2,334 8,989 (1,972) 3,701 10,718 Other liabilities 2,764 434 150 536 124 7 3 255 31 211 4,515 (511) 2,175 6,179 For the year ended December 31, 2018: Additions to property, plant and equipment 96 7 30 11 10 - - 9 3 6 172 (16) 145 301 As at December 31, 2017: Cash and cash equivalents $ 21 $ 14 $ 40 $ 18 $ 19 $ 7 $ 103 $ 90 $ 11 $ 7 330 $ (30) $ 499 $ 799 Property, plant and equipment, at fair value 11,396 1,303 1,908 1,798 482 304 11 602 625 - 18,429 (1,451) 10,118 27,096 Total assets 11,709 1,574 2,149 1,888 532 443 31 765 691 180 19,962 (1,040) 11,982 30,904 Total borrowings 3,049 447 200 1,005 233 192 9 499 253 2,552 8,439 (848) 4,175 11,766 Other liabilities 2,188 354 180 333 101 16 9 74 51 234 3,540 (191) 1,507 4,856 For the year ended December 31, 2017: Additions to property, plant and equipment 90 8 59 6 34 - - - 13 10 220 (10) 144 354
The following table presents consolidated revenue split by geographical region:	(MILLIONS) 2018 2017 2016 United States $ 926 $ 871 $ 786 Colombia 896 797 819 Canada 428 480 442 Brazil 429 366 269 Europe 126 111 136 Asia 177 - - $ 2,982 $ 2,625 $ 2,452
The following table presents consolidated property, plant and equipment and equity-accounted investments split by geographical region:	Dec 31 Dec 31 (MILLIONS) 2018 2017 United States $ 12,705 $ 11,131 Colombia 6,665 5,401 Canada 5,705 5,810 Brazil 3,553 3,479 Europe 1,624 1,332 Asia 342 664 $ 30,594 $ 27,817

OTHER INCOME (Tables)

OTHER INCOME (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables other income for the year ended December 31 is comprised of the following:	(MILLIONS) Notes 2018 2017 2016 Interest income and other $ 22 $ 32 $ 41 Gain on available for sale investments - 15 - Gains on settlement of foreign currency contracts 28 - 23 $ 50 $ 47 $ 64

DIRECT OPERATING COSTS (Tables)

DIRECT OPERATING COSTS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables direct operating costs for the year ended December 31 are comprised of the following:	(MILLIONS) Notes 2018 2017 2016 Operations, maintenance and administration $ 581 $ 567 $ 553 Water royalties, property taxes and other 142 161 149 Fuel and power purchases (1) 289 226 313 Energy marketing fees 27 24 24 23 $ 1,036 $ 978 $ 1,038 F uel and power purchase s are primarily attributable to our portfolio in Colombia.

OTHER (Tables)

OTHER (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables other for the year ended December 31 is comprised of the following:	(MILLIONS) 2018 2017 2016 Transaction costs $ 2 $ 9 $ 22 Change in fair value of property, plant and equipment 44 33 36 Other 36 (27) (12) $ 82 $ 15 $ 46

FOREIGN CURRENCY TRANSLATION (T

FOREIGN CURRENCY TRANSLATION (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables foreign currency translation for the year ended December 31 shown in the consolidated statements of comprehensive income is comprised of the following:	(MILLIONS) Notes 2018 2017 2016 Foreign currency translation on Property, plant and equipment, at fair value 12 $ (1,512) $ 506 $ 1,186 Borrowings 13 537 (282) (244) Deferred income tax liabilities and assets 11 184 (82) (157) Other assets and liabilities (34) 48 201 $ (825) $ 190 $ 986

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The major components of income tax recovery (expense) for the year ended December 31 are as follows:	(MILLIONS) 2018 2017 2016 Deferred income taxes attributed to: Financial instruments designated as cash flow hedges $ (2) $ (4) $ 2 Other (20) 15 (7) Revaluation surplus Origination and reversal of temporary differences (1,117) (248) (55) Relating to changes in tax rates / imposition of new tax laws 54 586 19 $ (1,085) $ 349 $ (41)
The major components of deferred income tax recovery (expense) for the year ended December 31 recorded directly to OCI are as follows:	(MILLIONS) 2018 2017 2016 Deferred income taxes attributed to: Financial instruments designated as cash flow hedges $ (2) $ (4) $ 2 Other (20) 15 (7) Revaluation surplus Origination and reversal of temporary differences (1,117) (248) (55) Relating to changes in tax rates / imposition of new tax laws 54 586 19 $ (1,085) $ 349 $ (41)
Brookfield Renewables effective income tax (expense) recovery for the year ended December 31 is different from its recovery at its statutory income tax rate due to the differences below:	(MILLIONS) 2018 2017 2016 Statutory income tax (expense) recovery (1) $ (100) $ (50) $ 5 Reduction (increase) resulting from: Increase in tax assets not recognized (8) (15) (9) Differences between statutory rate and future tax rate 95 (37) 43 Subsidiaries' income taxed at different rates 75 14 14 Other (3) - - Effective income tax recovery (expense) $ 59 $ (88) $ 53 Statutory income tax expense is calculated at the domestic rates applicable to the profits in the country concerned.
The following table details the expiry date, if applicable, of the unrecognized deferred tax assets as at December 31:	(MILLIONS) 2018 2017 2016 2019 to 2023 $ 3 $ 8 $ - 2024 and thereafter 85 108 98 $ 88 $ 116 $ 98
The deferred tax assets and liabilities of the following temporary differences have been recognized in the consolidated financial statements for the year ended December 31:	Difference Net deferred Non-capital between tax and tax (liabilities) (MILLIONS) losses carrying value assets As at January 1, 2016 $ 458 $ (2,996) $ (2,538) Recognized in Net income (loss) 24 73 97 Recognized in equity 17 (48) (31) Business combination - (1,020) (1,020) Foreign exchange - (160) (160) As at December 31, 2016 499 (4,151) (3,652) Recognized in Net income (loss) (97) 48 (49) Recognized in equity 13 341 354 Business combination 79 (63) 16 Foreign exchange 14 (94) (80) As at December 31, 2017 508 (3,919) (3,411) Recognized in Net income (loss) (60) 149 89 Recognized in equity 1 (985) (984) Business combination - 73 73 Foreign exchange (20) 204 184 As at December 31, 2018 $ 429 $ (4,478) $ (4,049)

PROPERTY, PLANT AND EQUIPMENT_2

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following table presents a reconciliation of property, plant and equipment at fair value:	(MILLIONS) Notes Hydro Wind Solar Other (1) Total (2) As at December 31, 2015 $ 14,847 $ 3,233 - $ 278 $ 18,358 Additions 269 71 - 18 358 Acquisitions through business combinations 3 5,731 10 - - 5,741 Items recognized through OCI Change in fair value 190 187 - 54 431 Foreign exchange 1,114 21 - 51 1,186 Items recognized through net income Change in fair value (17) (10) - (9) (36) Depreciation (565) (199) - (17) (781) As at December 31, 2016 $ 21,569 $ 3,313 - $ 375 $ 25,257 Additions 253 95 - 6 354 Acquisitions through business combinations 3 - 670 575 - 1,245 Disposal - (338) - - (338) Items recognized through OCI Change in fair value 828 91 - (32) 887 Foreign exchange 332 177 - (3) 506 Items recognized through net income Change in fair value (20) (8) - (5) (33) Depreciation (563) (197) - (22) (782) As at December 31, 2017 $ 22,399 $ 3,803 $ 575 $ 319 $ 27,096 Additions 212 36 47 6 301 Acquisitions through business combinations 3 - 125 86 - 211 Transfer to assets held for sale 4 - (58) (691) - (749) Items recognized through OCI Change in fair value 3,775 466 313 4 4,558 Foreign exchange (1,138) (256) (77) (41) (1,512) Items recognized through net income Change in fair value (33) (20) - (8) (61) Depreciation (536) (236) (25) (22) (819) As at December 31, 2018 $ 24,679 $ 3,860 $ 228 $ 258 $ 29,025 Includes biomass and cogeneration. Includes intangible assets of $ 11 million ( 2017 : $ 1 3 million and 2016: $14 million ) and assets under construction of $ 388 million (201 7 : $ 601 million and 2016: $ 663 million ).
Discount rates, terminal capitalization rates and exit dates used in the valuation methodology, are provided in the following table:	North America Colombia Brazil Europe 2018 2017 2018 2017 2018 2017 2018 2017 Discount rate (1) Contracted 4.8% - 5.6% 4.9% - 6.0% 9.6% 11.3% 9.0% 8.9% 4.0% - 4.3% 4.1% - 4.5% Uncontracted 6.4% - 7.2% 6.5% - 7.6% 10.9% 12.6% 10.3% 10.2% 5.8% - 6.1% 5.9% - 6.3% Terminal capitalization rate (2) 6.1% - 7.1% 6.2% - 7.5% 10.4% 12.6% N/A N/A N/A N/A Exit date 2038 2037 2038 2037 2047 2032 2033 2031 Discount rates are not adjusted for asset specific risks. The terminal capitalization rate applies only to hydroelectric assets in the United States, Canada and Colombia.
The following table summarizes the impact of a change in discount rates, electricity prices and terminal capitalization rates on the fair value of property, plant and equipment:	2018 North (MILLIONS) America Colombia Brazil Europe Total 25 bps increase in discount rates $ (770) $ (180) $ (80) $ (20) $ (1,050) 25 bps decrease in discount rates 840 190 80 20 1,130 5% increase in future electricity prices 800 370 100 20 1,290 5% decrease in future electricity prices (800) (370) (100) (20) (1,290) 25 bps increase in terminal capitalization rate (1) (210) (30) - - (240) 25 bps decrease in terminal capitalization rate (1) 230 30 - - 260 2017 North (MILLIONS) America Colombia Brazil Europe Total 25 bps increase in discount rates $ (710) $ (130) $ (50) $ (20) $ (910) 25 bps decrease in discount rates 770 130 50 20 970 5% increase in future electricity prices 620 310 70 20 1,020 5% decrease in future electricity prices (620) (310) (70) (20) (1,020) 25 bps increase in terminal capitalization rate (1) (180) (20) - - (200) 25 bps decrease in terminal capitalization rate (1) 190 20 - - 210 The terminal capitalization rate applies only to hydroelectric assets in the United States, Canada and Colombia .
The following table summarizes the percentage of total generation contracted under power purchase agreements, power prices from long-term power purchase agreements that are linked specifically to the related power generating assets, and the estimates of future electricity prices:	North America Colombia Brazil Europe 1 - 10 years 57% 22% 69% 72% 11 - 20 years 34% 0% 35% 25% Per MWh (1) North America Colombia Brazil Europe 1 - 10 years $ 83 COP 201,000 R$ 286 € 93 11 - 20 years 80 - 397 111 Assumes nominal prices based on weighted-average generation. Per MWh (1) North America Colombia Brazil Europe 1 - 10 years $ 68 COP 252,000 R$ 287 € 79 11 - 20 years 116 354,000 452 92 Assumes nominal prices based on weighted-average generation.
Had Brookfield Renewables revalued property, plant and equipment been measured on a historical cost basis, the carrying amounts, net of accumulated depreciation would have been as follows at December 31:	(MILLIONS) 2018 2017 Hydroelectric $ 11,888 $ 12,740 Wind 2,753 3,030 Solar 260 621 Other (1) 246 312 $ 15,147 $ 16,703 Includes biomass and co g eneration.

BORROWINGS (Tables)

BORROWINGS (Tables)	12 Months Ended
	Dec. 31, 2018
Detailed Information About Borrowings
The following table outlines changes in Brookfield Renewables borrowings for the year ended December 31	Net cash flows from Non-cash (MILLIONS) Jan 1 financing activities Acquisition Held for sale Disposal Other (1) Dec 31 2018 Corporate borrowings $ 2,552 (88) - - - (130) $ 2,334 Non-recourse borrowings $ 9,214 (178) 90 (360) - (382) $ 8,384 2017 Corporate borrowings $ 2,229 191 - - - 132 $ 2,552 Non-recourse borrowings $ 7,953 76 1,188 - (173) 170 $ 9,214 Includes foreign exchange and amortization of unamortized premium and financing fees.
Corporate Borrowings
Detailed Information About Borrowings
The composition of debt obligations as at December 31 is presented in the following table	2018 2017 Weighted-average Estimated Weighted-average Estimated Interest Term Carrying fair Interest Term Carrying fair (MILLIONS EXCEPT AS NOTED) rate (%) (years) value value rate (%) (years) value value Credit facilities 3.3 4.4 $ 727 $ 727 2.6 4.5 $ 887 $ 887 Medium Term Notes: Series 3 (C$200) - - $ - $ - 5.3 0.8 $ 159 $ 163 Series 4 (C$150) 5.8 17.9 110 124 5.8 18.9 119 144 Series 7 (C$450) 5.1 1.8 330 342 5.1 2.8 358 382 Series 8 (C$400) 4.8 3.1 293 309 4.8 4.1 318 344 Series 9 (C$400) 3.8 6.4 293 288 3.8 7.4 318 321 Series 10 (C$500) 3.6 8.0 367 357 3.6 9.0 398 400 Series 11 (C$300) 4.3 10.0 220 220 - - - - 4.4 6.5 $ 1,613 $ 1,640 4.5 6.4 $ 1,670 $ 1,754 Total corporate borrowings 2,340 2,367 2,557 2,641 Less: Unamortized financing fees (1) (6) (5) Less: Current portion (6) (159) $ 2,328 $ 2,393 Unamortized premiums and unamortized financing fees are amortized over the terms of the borrowing.
The following table summarizes the available portion of credit facilities as at December 31	(MILLIONS) 2018 2017 Authorized corporate credit facilities (1) $ 2,100 $ 2,090 Draws on corporate credit facilities (1) (721) (685) Issued letters of credit (8) (193) Available portion of corporate credit facilities 1,371 1,212 Amounts are guaranteed by Brookfield Renewable. Excludes $ 6 million ( 2017 : $ 202 million) borrowed under a subscription facility of a Brookfield sponsored private fund.
The following table outlines the change in the unamortized financing fees of corporate borrowings for the year ended December 31	(MILLIONS) 2018 2017 2016 Corporate borrowings Unamortized financing fees, beginning of year $ 5 $ 6 $ 5 Additional financing fees 2 - 2 Amortization of financing fees (1) (1) (1) Unamortized financing fees, end of year $ 6 $ 5 $ 6
Non Recourse Borrowings
Detailed Information About Borrowings
The composition of debt obligations as at December 31 is presented in the following table	2018 2017 Weighted-average Estimated Weighted-average Estimated Interest Term Carrying fair Interest Term Carrying fair (MILLIONS EXCEPT AS NOTED) rate (%) (years) value value rate (%) (years) value value Non-recourse borrowings Hydroelectric 6.1 9.2 $ 6,318 $ 6,517 6.3 8.8 $ 6,392 $ 6,813 Wind 4.7 10.8 1,908 1,951 5.8 9.7 2,211 2,343 Solar 6.0 7.1 142 133 11.1 7.6 643 643 Storage and other 4.0 4.9 91 95 8.4 17.8 39 39 Total 5.7 9.5 $ 8,459 $ 8,696 6.5 9.0 $ 9,285 $ 9,838 Add: Unamortized premiums (1) 1 1 Less: Unamortized financing fees (1) (76) (72) Less: Current portion (489) (1,517) $ 7,895 $ 7,697 Unamortized premiums and unamortized financing fees are amortized over the terms of the borrowing.
The following table outlines the change in the unamortized financing fees of corporate borrowings for the year ended December 31	(MILLIONS) 2018 2017 2016 Non-recourse borrowings Unamortized financing fees, beginning of year $ 72 $ 74 $ 54 Additional financing fees 21 16 41 Amortization of financing fees (12) (14) (17) Foreign exchange translation and other (5) (4) (4) Unamortized financing fees, end of year $ 76 $ 72 $ 74
Future repayments of Brookfield Renewables debt obligations, for each of the next five years and thereafter are as follows	(MILLIONS) 2019 2020 2021 2022 2023 Thereafter Total Non-recourse borrowings Hydro 306 446 164 491 1,084 3,827 6,318 Wind 169 119 129 128 161 1,202 1,908 Solar 13 - 4 - - 125 142 Storage and other 1 1 77 1 1 10 91 $ 489 $ 566 $ 374 $ 620 $ 1,246 $ 5,164 $ 8,459

NON-CONTROLLING INTERESTS (Tabl

NON-CONTROLLING INTERESTS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables non-controlling interests are comprised of the following as at December 31:	(MILLIONS) 2018 2017 Participating non-controlling interests - in operating subsidiaries $ 8,129 $ 6,298 General partnership interest in a holding subsidiary held by Brookfield 66 58 Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield 3,252 2,843 Preferred equity 568 616 $ 12,015 $ 9,815
The net change in participating non-controlling interests in operating entities is as follows:	Brookfield Isagen Isagen public Americas Brookfield Brookfield Canadian The institu- non-con Infrastructure Infrastructure Infrastructure Hydroelectric Catalyst tional -trolling (MILLIONS) Fund Fund II Fund III Portfolio Group investors interests Other Total As at December 31, 2015 $ 958 $ 1,441 $ - $ - $ 121 $ - $ - $ 67 $ 2,587 Net income (18) (16) 15 - 16 47 19 2 65 OCI 46 228 - - 2 148 205 6 635 Capital contributions - 74 1,074 - - 1,473 - - 2,621 Acquisition - - - - - - 1,417 - 1,417 Distributions (23) (73) (7) - (12) - - (4) (119) MTO adjustments - - 3 - - 7 (1,627) - (1,617) As at December 31, 2016 $ 963 $ 1,654 $ 1,085 $ - $ 127 $ 1,675 $ 14 $ 71 $ 5,589 Net (loss) income (29) (13) 33 - 12 47 - 3 53 OCI (76) 269 111 - 2 78 (1) - 383 Capital contributions - 89 186 - - 19 - - 294 Acquisition - - 525 - - - - - 525 Distributions (8) (317) (88) - (7) (115) - (4) (539) Purchase of Isagen shares - - (1) - - (5) 5 - (1) Other - - 1 - - 2 (9) - (6) As at December 31, 2017 $ 850 $ 1,682 $ 1,852 $ - $ 134 $ 1,701 $ 9 $ 70 $ 6,298 Net income 1 9 86 4 14 174 1 8 297 OCI 66 298 805 (11) (18) 504 5 58 1,707 Capital contributions - 9 5 293 - - - - 307 Acquisition - - - - - - - 21 21 Distributions (17) (81) (276) - (6) (167) - (6) (553) Other - 12 (3) (10) - - - 53 52 As at December 31, 2018 $ 900 $ 1,929 $ 2,469 $ 276 $ 124 $ 2,212 $ 15 $ 204 $ 8,129 Interests held by third parties 75-80% 43-60% 23-71% 25-44% 25% 53% 0.5% 20-50% -
The following tables summarize certain financial information of operating subsidiaries that have non-controlling interests that are material to Brookfield Renewable:	Brookfield Americas Brookfield Brookfield Canadian The Infrastructure Infrastructure Infrastructure Hydroelectric Catalyst (MILLIONS) Fund Fund II Fund III (1) Portfolio Group Isagen (2) Other Total Interests held by third parties 75-80% 43-60% 69-71% 25-44% 25% 76% 20-50% Place of business United States, Brazil United States, Brazil, Europe United States, Brazil, India, China Canada United States Colombia United States, Brazil, Canada Year ended December 31, 2016: Revenue $ 118 $ 394 $ 28 $ - $ 164 $ 819 $ 27 $ 1,550 Net income (22) (23) (8) - 62 110 5 124 Total comprehensive income (loss) 37 356 (8) - 70 502 31 988 Net income allocated to non-controlling interests (18) (16) (5) - 16 86 2 65 Year ended December 31, 2017: Revenue $ 123 $ 430 $ 53 $ - $ 135 $ 797 $ 32 $ 1,570 Net (loss) income (34) (20) 18 - 47 89 7 107 Total comprehensive income (loss) (133) 529 126 - 57 236 - 815 Net (loss) income allocated to non-controlling interests (29) (13) 13 - 12 67 3 53 As at December 31, 2017: Property, plant and equipment, at fair value $ 1,667 $ 5,153 $ 2,149 $ - $ 964 $ 5,401 $ 411 $ 15,745 Total assets 1,718 5,430 3,294 - 1,066 6,526 426 18,460 Total borrowings 556 2,040 1,502 - 413 1,858 42 6,411 Total liabilities 628 2,422 1,678 - 432 3,336 63 8,559 Carrying value of non-controlling interests $ 850 $ 1,682 $ 1,138 $ - $ 134 $ 2,424 $ 70 $ 6,298 Year ended December 31, 2018: Revenue $ 157 $ 447 $ 311 $ 38 $ 142 $ 896 $ 21 $ 2,012 Net income 2 17 19 15 56 331 2 442 Total comprehensive income (loss) 95 544 898 25 (16) 1,290 16 2,852 Net income allocated to non-controlling interests 1 9 15 6 14 251 1 297 As at December 31, 2018: Property, plant and equipment, at fair value $ 1,687 $ 5,553 $ 2,322 $ 1,679 $ 875 $ 6,665 $ 253 $ 19,034 Total assets 1,737 5,831 3,725 1,975 982 7,717 293 22,260 Total borrowings 536 1,979 838 924 369 1,744 70 6,460 Total liabilities 582 2,395 1,441 1,933 387 3,548 88 10,374 Carrying value of non-controlling interests $ 900 $ 1,929 $ 1,641 $ 314 $ 124 $ 3,169 $ 52 $ 8,129 Excludes information relating to Isagen which is presented separately. T he total third parties ownership interest in Isagen as of December 31, 2018 was 75.9% and comprised of Brookfield Infrastructure Fund III: 22.9 %, Isagen Institut ional investors 52.5 % and other non-controlling interests: 0.5 %.
The composition of the distributions for the year ended December 31 is presented in the following table:	(MILLIONS) 2018 2017 General partnership interest in a holding subsidiary held by Brookfield $ 5 $ 5 Incentive distribution 40 30 $ 45 $ 35 Participating non-controlling interests - in a holding subsidiary - Redeemable/ Exchangeable units held by Brookfield $ 255 $ 243 $ 300 $ 278
The following table summarizes certain financial information regarding General partnership interest in a holding subsidiary held by Brookfield and Participating non-controlling interests in a holding subsidiary Redeemable or Exchangeable units held by Brookfield:	(MILLIONS) 2018 2017 2016 For the year ended December 31 : Revenue $ 2,982 $ 2,625 $ 2,452 Net income 403 51 40 Comprehensive income 3,667 1,401 1,369 Net income allocated to (1) : GP interest 1 (1) - Redeemable/Exchangeable partnership units 17 (23) (29) As at December 31 : Property, plant and equipment, at fair value $ 29,025 $ 27,096 Total assets 34,103 30,904 Total borrowings 10,718 11,766 Total liabilities 16,897 16,622 Carrying value of (2) : GP interest 66 58 Redeemable/Exchangeable partnership units 3,252 2,843 Allocated based on weighted-average GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 180.2 million, respectively ( 2017 : 2.7 million, 129.7 million, and 173.5 million, respectively and 2016 : 2.7 million, 129.7 million, and 156.4 million, respectively). Allocated based on outstanding GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 178.8 million, respectively ( 2017 : 2.7 m illion, 129.7 million, and 180.4 million, respectively).
Brookfield Renewables preferred equity as at December 31 consists of Class A Preference Shares of Brookfield Renewable Power Preferred Equity Inc. (BRP Equity) as follows:	Earliest Dividends declared for Cumulative permitted the year ended Carrying value as at (MILLIONS, EXCEPT Shares dividend redemption December 31 AS NOTED) outstanding rate (%) date 2018 2017 2018 2017 Series 1 (C$136) 5.45 3.36 Apr 2020 $ 4 $ 4 $ 100 $ 108 Series 2 (C$113) (1) 4.51 4.29 Apr 2020 3 3 83 90 Series 3 (C$249) 9.96 4.40 Jul 2019 8 8 182 197 Series 5 (C$103) 4.11 5.00 Apr 2018 4 4 75 82 Series 6 (C$175) 7.00 5.00 Jul 2018 7 7 128 139 31.03 $ 26 $ 26 $ 568 $ 616 Dividend rate represents annualized distribution based on the most recent quarterly floating rate .

PREFERRED LIMITED PARTNERS EQ_2

PREFERRED LIMITED PARTNERS EQUITY (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Disclsoure of preferred limited partners equity [text block]	Earliest Distributions declared for Cumulative permitted the year ended Carrying value as at (MILLIONS, EXCEPT Shares distribution redemption December 31 Dec 31 Dec 31 AS NOTED) outstanding rate (%) date 2018 2017 2018 2017 Series 5 (C$72) 2.89 5.59 Apr 2018 $ 4 $ 4 $ 49 $ 49 Series 7 (C$175) 7.00 5.50 Jan 2021 7 8 128 128 Series 9 (C$200) 8.00 5.75 Jul 2021 9 8 147 147 Series 11 (C$250) 10.00 5.00 Apr 2022 9 8 187 187 Series 13 (C$250) 10.00 5.00 Apr 2023 9 - 196 - 37.89 $ 38 $ 28 $ 707 $ 511

LIMITED PARTNERS EQUITY (Tables

LIMITED PARTNERS EQUITY (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The composition of the distributions for the year ended December 31 is presented in the following table:	(MILLIONS) 2018 2017 General partnership interest in a holding subsidiary held by Brookfield $ 5 $ 5 Incentive distribution 40 30 $ 45 $ 35 Participating non-controlling interests - in a holding subsidiary - Redeemable/ Exchangeable units held by Brookfield $ 255 $ 243 $ 300 $ 278

GOODWILL (Tables)

GOODWILL (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following table provides a reconciliation of goodwill:	(MILLIONS) Notes Total Balance, as at December 31, 2016 $ 896 Foreign exchange 5 Balance, as at December 31, 2017 $ 901 Acquired through acquisition 3 27 Transfer to Assets held for sale 4 (22) Foreign exchange (78) Balance, as at December 31, 2018 $ 828

EQUITY-ACCOUNTED INVESTMENTS (T

EQUITY-ACCOUNTED INVESTMENTS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following table outlines the changes in Brookfield Renewables equity-accounted investments for the year ended December 31:	(MILLIONS) 2018 2017 2016 Balance, beginning of year $ 721 $ 206 $ 197 Investment 420 469 - Share of net income 68 2 - Share of other comprehensive income 426 56 8 Dividends received (42) (31) (6) Foreign exchange translation and other (24) 19 7 Balance, end of year $ 1,569 $ 721 $ 206
The following tables summarize certain financial information of equity-accounted investments:	(MILLIONS) 2018 2017 2016 For the year ended December 31 Revenue $ 1,305 310 $ 74 Net income (loss) 223 (24) - Share of net income (1) 68 2 - (1) Brookfield Renewable's ownership interest in these entities ranges from 14-50%. (MILLIONS) 2018 2017 As at December 31: Current assets $ 682 $ 477 Property, plant and equipment, at fair value 11,999 8,098 Other assets 608 213 Current liabilities 1,080 687 Non-recourse borrowings 6,078 4,294 Other liabilities 1,197 822

CASH AND CASH EQUIVALENTS (Tabl

CASH AND CASH EQUIVALENTS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables cash and cash equivalents as at December 31 are as follows:	(MILLIONS) 2018 2017 Cash $ 127 $ 790 Short-term deposits 46 9 $ 173 $ 799

RESTRICTED CASH (Tables)

RESTRICTED CASH (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables restricted cash as at December 31 is as follows:	(MILLIONS) Note 2018 2017 Operations $ 119 $ 195 Credit obligations 60 85 Capital expenditures and development projects 2 4 Total 181 284 Less: non-current 23 (45) (103) Current $ 136 $ 181

TRADE RECEIVABLES AND OTHER C_2

TRADE RECEIVABLES AND OTHER CURRENT ASSETS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables trade receivables and other current assets as at December 31 are as follows:	(MILLIONS) 2018 2017 Trade receivables $ 339 $ 360 Prepaids and others 114 112 Other short-term receivables 109 82 Current portion of contract asset 45 - $ 607 $ 554

ACCOUNTS PAYABLE AND ACCRUED _2

ACCOUNTS PAYABLE AND ACCRUED LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Brookfield Renewables accounts payable and accrued liabilities as at December 31 are as follows:	(MILLIONS) 2018 2017 Operating accrued liabilities $ 263 $ 271 Accounts payable 76 117 Interest payable on corporate and non-recourse borrowings 76 64 Deferred consideration 30 35 LP Unitholders’ distributions, preferred limited partnership unit distributions and preferred dividends payable (1) 30 29 Other 58 26 $ 533 $ 542 Includes amounts payable only to external LP Unitholders. Amounts payable to Brookfield are included in due to related parties.

COMMITMENTS, CONTINGENCIES AN_2

COMMITMENTS, CONTINGENCIES AND GUARANTEES (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
As at December 31, Brookfield Renewable had commitments for future minimum lease payments under non-cancellable leases which fall due as follows:	(MILLIONS) 2019 $ 31 2020 29 2021 25 2022 22 2023 18 Thereafter 125 Total $ 250
As at December 31, letters of credit issued by Brookfield Renewable along with institutional investors and its subsidiaries were as follows:	(MILLIONS) 2018 2017 Brookfield Renewable along with institutional investors $ 51 $ 76 Brookfield Renewable's subsidiaries 338 468 $ 389 $ 544

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following table reflects the related party agreements and transactions in the consolidated statements of income, for the year ended December 31:	(MILLIONS) 2018 2017 2016 Revenues Power purchase and revenue agreements $ 535 $ 601 $ 527 Wind levelization agreement 7 6 8 $ 542 $ 607 $ 535 Direct operating costs Energy purchases $ (20) $ (13) $ (3) Energy marketing fee (24) (24) (23) Insurance services (25) (19) (20) $ (69) $ (56) $ (46) Interest (expense) income - borrowings $ (8) $ - $ 6 Management service costs $ (80) $ (82) $ (62)

SUPPLEMENTAL INFORMATION (Table

SUPPLEMENTAL INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The net change in working capital balances for the year ended December 31 shown in the consolidated statements of cash flows is comprised of the following:	(MILLIONS) 2018 2017 2016 Trade receivables and other current assets $ (122) $ (40) $ 30 Accounts payable and accrued liabilities 32 32 (160) Other assets and liabilities 22 (17) (7) $ (68) $ (25) $ (137)

PENSION AND EMPLOYEE FUTURE B_2

PENSION AND EMPLOYEE FUTURE BENEFITS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
Actuarial assumptions as at December 31:	(%) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Discount rate 2.5 - 7.2 3.9 - 7.4 2.4 - 7.3 3.7 - 7.1 2.2 - 7.3 4.1 - 7.3 Rate of price inflation 1.5 - 3.5 N/A 1.5 - 3.5 N/A 1.5 - 3.5 N/A Rate of compensation increases 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 Health care trend rate (1) N/A 5.3 - 6.9 N/A 5.3 - 6.9 N/A 5.3 - 6.9 Assumed immediate trend rate at year-end.
A 50 basis point change in the assumptions mentioned before, used for the calculation of the benefit obligations as at December 31, would result in the following increase (decrease) of the benefit obligations:	Defined benefit Non-pension (MILLIONS) pension plans benefit plans Discount rate 50 basis point increase $ (7) $ (4) 50 basis point decrease 8 4 Rate of price inflation and inflation-linked assumptions 50 basis point increase 4 N/A 50 basis point decrease (4) N/A Health care cost trend rate 50 basis point increase N/A 3 50 basis point decrease N/A (3)
Expense recognized in the consolidated statements of income and consolidated statements of comprehensive income for the year ended December 31:	(MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Current service costs $ 3 $ 2 $ 3 $ 1 $ 3 $ 1 Past service costs (recovery) - - (1) - - - Interest expense 2 3 2 3 2 3 Administrative expenses 1 - 1 - 1 - Recognized in consolidated statement of income 6 5 5 4 6 4 Remeasurement of the net defined benefit liability: Return on plan assets 5 - (8) - (2) - Actuarial changes arising from changes in demographic assumptions (1) - 1 (2) (1) (1) Actuarial changes arising from changes in financial assumptions (9) (4) 7 3 5 1 Experience adjustments 1 (1) - 1 - - Recognized in consolidated statement of comprehensive income (4) (5) - 2 2 - Total $ 2 $ - $ 5 $ 6 $ 8 $ 4
The amounts included in the consolidated statements of financial position arising from Brookfield Renewables obligations in respect of its defined benefit plans are as follows:	(MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Present value of defined benefit obligation $ 157 $ 53 $ 172 $ 57 $ 158 $ 53 Fair value of plan assets (126) (4) (135) (5) (119) (5) Net liability $ 31 $ 49 $ 37 $ 52 $ 39 $ 48
The movement in the defined benefit obligation for the year ended December 31 is as follows:	(MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Balance, beginning of year $ 172 $ 57 $ 158 $ 53 $ 124 $ 35 Current service cost 3 2 3 1 3 1 Past service (recovery) cost - - (1) - - - Interest expense 7 3 7 3 7 3 Remeasurement losses (gains) Actuarial changes arising from changes in demographic assumptions (1) - 1 (2) (1) (1) Actuarial changes arising from changes in financial assumptions (9) (4) 7 3 5 1 Experience adjustments 1 (1) - 1 - - Benefits paid (9) (2) (7) (2) (8) (2) Business combination - - - - 25 14 Exchange differences (7) (2) 4 - 3 2 Balance, end of year $ 157 $ 53 $ 172 $ 57 $ 158 $ 53
The movement in the fair value of plan assets for the year ended December 31 is as follows:	(MILLIONS) 2018 2017 2016 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans Balance, beginning of year $ 135 $ 5 $ 119 $ 5 $ 103 $ - Interest income 5 - 5 - 5 - Return on plan assets (5) (1) 8 - 2 - Employer contributions 5 2 5 2 7 3 Business combination - - - - 9 4 Benefits paid (9) (2) (7) (2) (8) (2) Exchange differences (5) - 5 - 1 - Balance, end of year $ 126 $ 4 $ 135 $ 5 $ 119 $ 5
The composition of plan assets as at December 31 is as follows:	(%) 2018 2017 Asset category: Cash and cash equivalents 2 2 Equity securities 47 54 Debt securities 51 44 100 100

SUBSIDIARY PUBLIC ISSUERS (Tabl

SUBSIDIARY PUBLIC ISSUERS (Tables)	12 Months Ended
	Dec. 31, 2018
Table Text Block [Abstract]
The following tables provide consolidated summary balance sheet infromation for Brookfield Renewable, BRP Equity, and Finco:	Includes investments in subsidiaries under the equity method. Includes BRELP, BRP Bermuda Holdings I Limited, Brookfield BRP Holdings (Canada) Inc. and Brookfield BRP Europe Holdings Limited, together the “Holding Entities”. Includes subsidiaries of Brookfield Renewable , other than BRP Equity , Finco and the Holding Entities . Includes elimination of intercompany transactions and balances necessary to present Brookfield Renewable on a consolidated basis .
The following tables provide consolidated summary Income Statement infromation for Brookfield Renewable, BRP Equity, and Finco:	Brookfield Brookfield BRP Holding Other Consolidating Renewable (MILLIONS) Renewable (1) Equity Finco Entities (1)(2) Subsidiaries (1)(3) adjustments (4) consolidated For the year ended December 31, 2018 Revenues $ - $ - $ - $ - $ 2,983 $ (1) $ 2,982 Net income (loss) 62 7 (1) (25) 1,305 (945) 403 For the year ended December 31, 2017 Revenues $ - $ - $ - $ - $ 2,625 $ - $ 2,625 Net income (loss) (4) 10 (1) (435) 631 (150) 51 For the year ended December 31, 2016 Revenues $ - $ - $ - $ 1 $ 2,451 $ - $ 2,452 Net income (loss) (20) - (1) (100) 558 (397) 40 Includes investments in subsidiaries under the equity method. Includes the Holding Entities . Includes subsidiaries of Brookfield Renewable , other than BRP Equity , Finco, and the Holding Entities . Includes elimination of intercompany transactions and balances necessary to present Brookfield Renewable on a consolidated basis.

BASIS OF PREPARATION AND SIGN_4

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Details - IFRS 9 Classification) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of effect of overlay approach reclassification on profit or loss [line items]
Cash and cash equivalents	$ 173	$ 799	$ 223	$ 63
Restricted cash	181	284	$ 284
Trade receivables and other current assets	607	554
Financial instrument assets	60	72
Due from related parties	65	60
Accounts payable and accrued liabilities	533	542
Financial instrument liabilities	27	184
Due to related parties	101	112
Long-term debt and credit facilities	2,328	2,393
Derivative financial instruments
Disclosure of effect of overlay approach reclassification on profit or loss [line items]
The net realized gains or losses on investments during the period	21	$ 16
Amortized cost (Financial Assets) | Carrying amount IAS 39 and IFRS 9
Disclosure of effect of overlay approach reclassification on profit or loss [line items]
Cash and cash equivalents	799
Restricted cash	284
Trade receivables and other current assets	554
Due from related parties	60
Accounts payable and accrued liabilities	542
Due to related parties	112
Long-term debt and credit facilities	9,214
FVOCI (Financial Assets) | Carrying amount IAS 39 and IFRS 9 | Investments in equity and debt
Disclosure of effect of overlay approach reclassification on profit or loss [line items]
Financial instrument assets	159
FVPL (Financial Assets) | Carrying amount IAS 39 and IFRS 9 | Derivative financial instruments
Disclosure of effect of overlay approach reclassification on profit or loss [line items]
Financial instrument assets	20
Financial instruments designated as hedges | Carrying amount IAS 39 and IFRS 9 | Derivative financial instruments designated as hedges
Disclosure of effect of overlay approach reclassification on profit or loss [line items]
Financial instrument assets	6
Financial instrument liabilities	125
FVPL (Financial Liabilities) | Carrying amount IAS 39 and IFRS 9 | Derivative financial instruments
Disclosure of effect of overlay approach reclassification on profit or loss [line items]
Financial instrument liabilities	$ 145

BASIS OF PREPARATION AND SIGN_5

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Details - Depreciation on power generating assets)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Dams
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 115 years
Penstocks
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 60 years
Powerhouses
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 115 years
Hydroelectric generating units
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 115 years
Wind generating units
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 30 years
Solar generating units
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 30 years
Gas-fired cogenerating (Cogeneration) units
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 40 years
Other assets
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	Up to 60 years
Concession asset | Brazil
Disclosure of detailed information about property, plant and equipment [line items]
Estimated service lives	29	15

PRINCIPAL SUBSIDIARIES (Details

PRINCIPAL SUBSIDIARIES (Details)	12 Months Ended
	Dec. 31, 2018
Alta Wind VIII LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
BIF II Safe Harbor Holdings LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
BIF III Holtwood LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
BRE GLBL Holdings L.P.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
BRI Green Energy Limited
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Brookfield BRP Canada Corp.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Brookfield Energia Comercializadora Ltda
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Brookfield Power US Holding America Co.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Brookfield Renewable UK Hydro Limited
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Brookfield Smoky Mountain Hydropower LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Brookfield White Pine Hydro LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Catalyst Old River Hydroelectric Limited Partnership
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	75.00%
Erie Boulevard Hydropower, L.P.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Great Lakes Hydro America, LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Great Lakes Power Limited
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	75.00%
Hawks Nest Hydro LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Isagen S.A. E.S.P.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	99.50%
Kwagis Power Limited Partnership
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	75.00%
Lievre Power L.P.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Mississagi Power Trust
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Orion Canadian Holdings 1 AIV L.P.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Powell River Energy Inc.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Rumford Falls Hydro LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Safe Harbor Water Power Corporation
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Tangara Energia S.A.
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
Windstar Energy, LLC
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%
2016 Comber Wind Limited Partnership
Disclosure of subsidiaries [line items]
Percentage of voting securities owned or controlled	100.00%

ACQUISITIONS (Details)

ACQUISITIONS (Details) € in Millions, £ in Millions, R$ in Millions, $ in Millions	Dec. 28, 2017USD ($)MW	Jan. 22, 2016USD ($)GWhMW	Oct. 31, 2018USD ($)	Mar. 31, 2018USD ($)MW	Dec. 31, 2017USD ($)MW	Oct. 31, 2017USD ($)MW	Aug. 31, 2017USD ($)	Feb. 28, 2017MW	Sep. 30, 2016USD ($)MW	Apr. 30, 2016USD ($)GWh	Jan. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2018USD ($)	Oct. 31, 2018GBP (£)	Oct. 31, 2018USD ($)	Aug. 31, 2017GBP (£)	Aug. 31, 2017USD ($)	Sep. 30, 2016EUR (€)	Sep. 30, 2016USD ($)	Jan. 31, 2016BRL (R$)	Jan. 31, 2016USD ($)
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Current portion of non-recourse borrowings					$ (1,517)								$ (489)
Non-recourse borrowings					(7,697)								(7,895)
Acqusitions Completed In 2018
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents													13
Trade receivables and other current assets													7
Property, plant and equipment, at fair value													211
Current liabilities													(7)
Current portion of non-recourse borrowings													(3)
Financial instruments													(2)
Long-term debt													(87)
Deferred income tax liabilities													(39)
Non-controlling interests													(21)
Fair value of net assets acquired													72
Goodwill													27
Purchase price													99
Brookfield Renewable | Acqusitions Completed In 2017
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents					611
Restricted cash					90
Trade receivables and other current assets					63
Financial instruments					20
Property, plant and equipment, at fair value					1,245
Deferred tax assets					18
Other long-term assets					94
Current liabilities					(77)
Current portion of non-recourse borrowings					(1,183)
Financial instruments					(15)
Non-recourse borrowings					(5)
Deferred income tax liabilities					(17)
Other long-term liabilities					(54)
Non-controlling interests					(1)
Fair value of net assets acquired					789
Brookfield Renewable | Acqusitions Completed In 2016
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents												$ 117
Restricted cash												0
Trade receivables and other current assets												177
Property, plant and equipment, at fair value												5,741
Other long-term assets												15
Current liabilities												(467)
Long-term debt												(899)
Non-recourse borrowings												(899)
Deferred income tax liabilities												(1,020)
Other long-term liabilities												(149)
Non-controlling interests												(1,417)
Fair value of net assets acquired												2,098
Goodwill												799
Purchase price												2,897
Biotherm | Acqusitions Completed In 2018
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents													12
Trade receivables and other current assets													7
Property, plant and equipment, at fair value													158
Current liabilities													(3)
Current portion of non-recourse borrowings													(3)
Financial instruments													(2)
Long-term debt													(69)
Deferred income tax liabilities													(35)
Non-controlling interests													(21)
Fair value of net assets acquired													44
Goodwill													27
Purchase price													71
Biotherm | Brookfield Renewable | Acqusitions Completed In 2018
Disclosure of detailed information about business combination [line items]
Total cash consideration transferred				$ 12
Total consideration				71
Deferred consideration				3
Acquisition costs incurred and capitalized				$ 1
Terraform Global | Acqusitions Completed In 2017
Disclosure of detailed information about business combination [line items]
Total consideration					657
Fair Value of Interest Held at Acquisition Date					100
Potential gain on sale					$ 250
Terraform Global | Brookfield Renewable | Acqusitions Completed In 2018
Disclosure of detailed information about business combination [line items]
Name of acquiree	TerraForm Global
Date of acquisition	December 28th, 2017
Aggregate Capacity, MW | MW	49
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Purchase price	$ 56
Terraform Global | Brookfield Renewable | Acqusitions Completed In 2018 | Top of range
Disclosure of detailed information about business combination [line items]
Acquisition of controlling interests, percent	70.00%
Terraform Global | Brookfield Renewable | Acqusitions Completed In 2018 | Bottom of range
Disclosure of detailed information about business combination [line items]
Acquisition of controlling interests, percent	65.00%
Terraform Global | Brookfield Renewable | Acqusitions Completed In 2017
Disclosure of detailed information about business combination [line items]
Name of acquiree					TerraForm Global
Percentage of voting equity interests Retained by Brookfield					31.00%
Aggregate Capacity, MW | MW					919
Total consideration					$ 202
Fair Value of Interest Held at Acquisition Date					30
Potential gain on sale					2
Acquisition costs incurred and capitalized					1
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents					611
Restricted cash					90
Trade receivables and other current assets					62
Financial instruments					20
Property, plant and equipment, at fair value					1,208
Deferred tax assets					18
Other long-term assets					94
Current liabilities					(73)
Current portion of non-recourse borrowings					(1,183)
Financial instruments					(15)
Non-recourse borrowings					(5)
Deferred income tax liabilities					(15)
Other long-term liabilities					(54)
Non-controlling interests					(1)
Fair value of net assets acquired					757
Northern Ireland Wind | Acqusitions Completed In 2018
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents													1
Trade receivables and other current assets													0
Property, plant and equipment, at fair value													53
Current liabilities													(4)
Current portion of non-recourse borrowings													0
Financial instruments													0
Long-term debt													(18)
Deferred income tax liabilities													(4)
Non-controlling interests													0
Fair value of net assets acquired													28
Goodwill													0
Purchase price													$ 28
Northern Ireland Wind | Brookfield Renewable | Acqusitions Completed In 2018
Disclosure of detailed information about business combination [line items]
Name of acquiree				Northern Ireland Wind
Acquisition of controlling interests, percent			40.00%	100.00%
Aggregate Capacity, MW | MW				23
Total consideration														£ 22	$ 28
Acquisition costs incurred and capitalized			$ 1
Northern Ireland Wind | Brookfield Renewable | Acqusitions Completed In 2017
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents					0
Restricted cash					0
Trade receivables and other current assets					1
Financial instruments					0
Property, plant and equipment, at fair value					37
Deferred tax assets					0
Other long-term assets					0
Current liabilities					(4)
Current portion of non-recourse borrowings					0
Financial instruments					0
Non-recourse borrowings					0
Deferred income tax liabilities					(2)
Other long-term liabilities					0
Non-controlling interests					0
Fair value of net assets acquired					$ 32
FHH Guernsey Ltd | Brookfield Renewable | Acqusitions Completed In 2017
Disclosure of detailed information about business combination [line items]
Name of acquiree							FHH Guernsey Ltd
Date of acquisition							August 2,017
Owership percentage																25.00%	25.00%
Percentage of voting equity interests Retained by Brookfield																7.00%	7.00%
Total consideration																£ 194	$ 248
TerraForm Power | Brookfield Renewable | Acqusitions Completed In 2017
Disclosure of detailed information about business combination [line items]
Name of acquiree						TerraForm Power, Inc
Date of acquisition						October 2,017
Percentage of voting equity interests Retained by Brookfield						16.00%
Aggregate Capacity, MW | MW						2,600
Fair Value of Interest Held at Acquisition Date						$ 203
Potential gain on sale						13
Acquisition costs incurred and capitalized						$ 1
European Wind | Brookfield Renewable | Acqusitions Completed In 2017
Disclosure of detailed information about business combination [line items]
Name of acquiree								European Wind
Date of acquisition								February 2,017
Acquisition of controlling interests, percent								100.00%
Aggregate Capacity, MW | MW								16
Total consideration																£ 24	$ 32
Acquisition costs incurred and capitalized							$ 1
Colombia | Brookfield Renewable | Acqusitions Completed In 2016
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents												113
Restricted cash												0
Trade receivables and other current assets												174
Property, plant and equipment, at fair value												4,772
Other long-term assets												15
Current liabilities												(463)
Long-term debt												(899)
Non-recourse borrowings												(899)
Deferred income tax liabilities												(1,019)
Other long-term liabilities												(149)
Non-controlling interests												(1,417)
Fair value of net assets acquired												1,127
Goodwill												799
Purchase price												1,926
Isagen S.A. E.S.P. | Brookfield Renewable | Acqusitions Completed In 2016
Disclosure of detailed information about business combination [line items]
Name of acquiree		Isagen S.A. E.S.P
Owership percentage		57.60%											99.50%
Aggregate Capacity, MW | MW		3,032
Annual generation Energy, GWh | GWh		15,000
Potential gain on sale												900
Acquisition costs incurred and capitalized		$ 13
Brazil | Brookfield Renewable | Acqusitions Completed In 2016
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents												4
Restricted cash												0
Trade receivables and other current assets												2
Property, plant and equipment, at fair value												100
Other long-term assets												0
Current liabilities												(3)
Long-term debt												0
Non-recourse borrowings												0
Deferred income tax liabilities												0
Other long-term liabilities												0
Non-controlling interests												0
Fair value of net assets acquired												103
Goodwill												0
Purchase price												103
51 MW hydroelectric portfolio | Brookfield Renewable | Acqusitions Completed In 2016
Disclosure of detailed information about business combination [line items]
Name of acquiree											51 MW hydroelectric portfolio
Percentage of voting equity interests Retained by Brookfield																				100.00%	100.00%
Total cash consideration transferred																				R$ 355	$ 88
Total consideration																				417	103
Deferred consideration																				35	9
Impact of the foreign currency contracts																				R$ 24	$ 6
Acquisition costs incurred and capitalized											$ 1
North America portfolio | Brookfield Renewable | Acqusitions Completed In 2016
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents												0
Restricted cash												0
Trade receivables and other current assets												1
Property, plant and equipment, at fair value												859
Other long-term assets												0
Current liabilities												(1)
Non-recourse borrowings												0
Deferred income tax liabilities												0
Other long-term liabilities												0
Non-controlling interests												0
Fair value of net assets acquired												859
Goodwill												0
Purchase price												859
Pennsylvania Hydro | Brookfield Renewable | Acqusitions Completed In 2016
Disclosure of detailed information about business combination [line items]
Name of acquiree										Pennsylvania Hydro
Date of acquisition										April 2,016
Total cash consideration transferred										$ 859
Annual generation Energy, GWh | GWh										1,109
Potential gain on sale										$ 46
Acquisition costs incurred and capitalized										$ 6
Pennsylvania | Brookfield Renewable | Acqusitions Completed In 2016
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents												0
Restricted cash												0
Trade receivables and other current assets												1
Property, plant and equipment, at fair value												859
Other long-term assets												0
Current liabilities												(1)
Long-term debt												0
Deferred income tax liabilities												0
Other long-term liabilities												0
Non-controlling interests												0
Fair value of net assets acquired												859
Goodwill												0
Purchase price												859
Ireland | Brookfield Renewable | Acqusitions Completed In 2016
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents												0
Restricted cash												0
Trade receivables and other current assets												0
Property, plant and equipment, at fair value												10
Other long-term assets												0
Current liabilities												0
Non-recourse borrowings												0
Deferred income tax liabilities												(1)
Other long-term liabilities												0
Non-controlling interests												0
Fair value of net assets acquired												9
Goodwill												0
Purchase price												$ 9
European Wind Portfolio (Ireland) | Brookfield Renewable | Acqusitions Completed In 2016
Disclosure of detailed information about business combination [line items]
Date of acquisition									September 2,016
Acquisition of controlling interests, percent									40.00%
Aggregate Capacity, MW | MW									19
Total cash consideration transferred																		€ 7	$ 8
Total consideration																		8	9
Deferred consideration																		€ 1	$ 1
Acquisition costs incurred and capitalized									$ 1

ASSETS HELD FOR SALE (Details -

ASSETS HELD FOR SALE (Details - Assets and Liabilites classified as held for sale) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Statement [Line Items]
Assets held for sale	$ 920	$ 0
Liabilities directly associated with assets held for sale	489	$ 0
Cumulative amount recognized in other comprehensive income relating to limited partners equity for the assets held for sale	21
Cash and cash equivalents
Statement [Line Items]
Assets held for sale	8
Restricted cash
Statement [Line Items]
Assets held for sale	47
Trade receivables and other current assets
Statement [Line Items]
Assets held for sale	28
Property, plant and equipment, at fair value
Statement [Line Items]
Assets held for sale	749
Goodwill
Statement [Line Items]
Assets held for sale	22
Other long-term assets
Statement [Line Items]
Assets held for sale	66
Current liabilities
Statement [Line Items]
Liabilities directly associated with assets held for sale	23
Long-term debt
Statement [Line Items]
Liabilities directly associated with assets held for sale	360
Other long-term liabilities
Statement [Line Items]
Liabilities directly associated with assets held for sale	$ 150

ASSETS HELD FOR SALE (Details_2

ASSETS HELD FOR SALE (Details - Portfolio Assets Held for Sale) ฿ in Millions, RM in Millions, R in Millions, $ in Millions	1 Months Ended
	Dec. 31, 2018MYR (RM)GWh	Jul. 31, 2018USD ($)GWh	Dec. 31, 2018THB (฿)	Dec. 31, 2018USD ($)	Jul. 31, 2018ZAR (R)
South Africa Portfolio
Portfolio Assets Held for Sale [Line Items]
Annual generation Energy, GWh | GWh		178
Total consideration		$ 166			R 2,031
South Africa Portfolio | Brookfield Renewable
Portfolio Assets Held for Sale [Line Items]
Total consideration | $		$ 50
Ownership interest		31.00%
Percentage of voting securities owned or controlled		100.00%
South Africa Portfolio | Brookfield Renewable | Top of range
Portfolio Assets Held for Sale [Line Items]
Ownership interest		49.00%
South Africa Portfolio | Brookfield Renewable | Bottom of range
Portfolio Assets Held for Sale [Line Items]
Ownership interest		30.00%
Thailand Portfolio
Portfolio Assets Held for Sale [Line Items]
Annual generation Energy, GWh | GWh	40
Total consideration			฿ 3,070	$ 95
Thailand Portfolio | Brookfield Renewable
Portfolio Assets Held for Sale [Line Items]
Total consideration | $				29
Ownership interest	31.00%
Percentage of voting securities owned or controlled	100.00%
Malaysia Portfolio
Portfolio Assets Held for Sale [Line Items]
Annual generation Energy, GWh | GWh	19
Total consideration	RM 154			37
Malaysia Portfolio | Top of range
Portfolio Assets Held for Sale [Line Items]
Ownership interest	5.00%
Malaysia Portfolio | Bottom of range
Portfolio Assets Held for Sale [Line Items]
Ownership interest	49.00%
Malaysia Portfolio | Brookfield Renewable
Portfolio Assets Held for Sale [Line Items]
Total consideration | $				$ 11
Ownership interest	31.00%

RISK MANAGEMENT AND FINANCIAL_3

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Sensitivity analysis) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount	$ 2,340	$ 2,557	$ 9,285
Energy Derivative Contracts | Impact Of 5% Increase
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	(4)	(1)	(3)
Effect on other comprehensive income	(7)	(10)	(3)
Energy Derivative Contracts | Impact Of 5% Decrease
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	4	1	3
Effect on other comprehensive income	7	10	3
Interest rate risk | Subsidiaries [member] | Floating interest rate [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount	3,764	4,176
Hedged item, liabilities	1,447	824
Interest rate risk | Impact Of One Percent Increase
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	(10)	17	(17)
Effect on other comprehensive income	42	54	115
Interest rate risk | Impact Of One Percent decrease
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	11	(17)	17
Effect on other comprehensive income	(42)	(54)	(115)
Currency risk | Impact Of 5% Increase
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	30	4	1
Effect on other comprehensive income	44	79	51
Currency risk | Impact Of 5% Decrease
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	(30)	(4)	(1)
Effect on other comprehensive income	$ (44)	$ (79)	$ (51)

RISK MANAGEMENT AND FINANCIAL_4

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Credit risk) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Of Credit Risk Exposure [Line Items]
Cash and cash equivalents	$ 173	$ 799	$ 223	$ 63
Restricted cash	181	284	284
Financial instrument assets			185
Due from related parties	65	60
Total			$ 502
Credit Risk
Disclosure Of Credit Risk Exposure [Line Items]
Cash and cash equivalents	173	799
Restricted cash	181	284
Trade and other current receivables excluding prepaid	493	442
Financial instrument assets	184	185
Due from related parties	65	60
Total	$ 960	$ 502

RISK MANAGEMENT AND FINANCIAL_5

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Cash obligations) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Accounts payable and accrued liabilities	$ 533	$ 542
Financial instrument liabilities	138	270
Due to related parties	101	112
Other long-term liabilities - concession payments	734	344
Corporate Borrowings	2,340	2,557	$ 9,285
Non Recourse Borrowings	7,895	7,697
Interest payable on long-term debt	4,167	4,255	$ 4,255
Cash obligations	15,753	17,035
Concession Payments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Other long-term liabilities - concession payments	15	14
Less than 1 Year
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Accounts payable and accrued liabilities	533	542
Financial instrument liabilities	27	184
Due to related parties	101	112
Corporate Borrowings	6	159
Non Recourse Borrowings	489	1,517
Interest payable on long-term debt	577	634
Cash obligations	1,734	3,149
Less than 1 Year | Concession Payments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Other long-term liabilities - concession payments	1	1
Between 2-5 years
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Accounts payable and accrued liabilities	0	0
Financial instrument liabilities	57	62
Due to related parties	0	0
Corporate Borrowings	1,344	1,563
Non Recourse Borrowings	2,806	3,024
Interest payable on long-term debt	1,906	1,924
Cash obligations	6,117	6,576
Between 2-5 years | Concession Payments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Other long-term liabilities - concession payments	4	3
Greater than 5 years
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Accounts payable and accrued liabilities	0	0
Financial instrument liabilities	54	24
Due to related parties	0	0
Corporate Borrowings	990	835
Non Recourse Borrowings	5,164	4,744
Interest payable on long-term debt	1,684	1,697
Cash obligations	7,902	7,310
Greater than 5 years | Concession Payments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Other long-term liabilities - concession payments	$ 10	$ 10

RISK MANAGEMENT AND FINANCIAL_6

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Fair value disclosures - Classes of assets and liabilities table) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 31, 2016	Dec. 31, 2015
Disclosure of classification of assets liabilities [line items]
Cash and cash equivalents	$ 173	$ 799	$ 223		$ 63
Restricted cash	136	181
Other Current Assets	109	82
Due from related parties	65	60
Financial instrument assets			185
Equity-accounted investments	1,569	721		$ 206	197
Property, plant and equipment, at fair value	29,025	27,096	25,257		18,358
Goodwill	828	901	896
Deferred income tax assets	91	177
Other long-term assets	505	230
Total assets	34,103	30,904
Accounts payable and accrued liabilities	533	542
Due to related parties	101	112
Borrowings	10,718		$ 11,766		$ 10,182
Deferred income tax liabilities	4,140	3,588
Other long-term liabilities	734	344
Total liabilities	$ 16,897	$ 16,622

RISK MANAGEMENT AND FINANCIAL_7

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Fair value hierarchy) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of financial assets [line items]
Cash and cash equivalents	$ 173	$ 799	$ 223	$ 63
Restricted Cash And Cash Equivalents	181	284	284
Financial instrument assets			185
Property, plant and equipment, at fair value	29,025	27,096	$ 25,257	$ 18,358
Disclosure Of Financial Liabilities [Line items]
Contingent consideration	(3)	(18)
Assets for which fair value is disclosed
Equity-accounted investments	703	278
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	(2,367)	(2,641)
Non Recourse Borrowings	7,895	7,697
Total	19,062	15,875
Level 1
Disclosure of financial assets [line items]
Cash and cash equivalents	173
Restricted Cash And Cash Equivalents	181
Property, plant and equipment, at fair value	0
Disclosure Of Financial Liabilities [Line items]
Contingent consideration	0
Assets for which fair value is disclosed
Equity-accounted investments	703
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	(1,640)
Non Recourse Borrowings	(370)
Total	(893)
Level 2
Disclosure of financial assets [line items]
Cash and cash equivalents	0
Restricted Cash And Cash Equivalents	0
Property, plant and equipment, at fair value	0
Disclosure Of Financial Liabilities [Line items]
Contingent consideration	0
Assets for which fair value is disclosed
Equity-accounted investments	0
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	(727)
Non Recourse Borrowings	(8,326)
Total	(9,067)
Level 3
Disclosure of financial assets [line items]
Cash and cash equivalents	0
Restricted Cash And Cash Equivalents	0
Property, plant and equipment, at fair value	29,025
Disclosure Of Financial Liabilities [Line items]
Contingent consideration	(3)
Assets for which fair value is disclosed
Equity-accounted investments	0
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	0
Non Recourse Borrowings	0
Total	29,022
Energy Derivative Contracts
Disclosure of financial assets [line items]
Financial instrument assets	3	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(22)	(19)
Energy Derivative Contracts | Level 1
Disclosure of financial assets [line items]
Financial instrument assets	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0
Energy Derivative Contracts | Level 2
Disclosure of financial assets [line items]
Financial instrument assets	3
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(22)
Energy Derivative Contracts | Level 3
Disclosure of financial assets [line items]
Financial instrument assets	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0
Interest Rate Swaps
Disclosure of financial assets [line items]
Financial instrument assets	9	6
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(116)	(155)
Interest Rate Swaps | Level 1
Disclosure of financial assets [line items]
Financial instrument assets	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0
Interest Rate Swaps | Level 2
Disclosure of financial assets [line items]
Financial instrument assets	9
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(116)
Interest Rate Swaps | Level 3
Disclosure of financial assets [line items]
Financial instrument assets	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0
Foreign exchange swaps
Disclosure of financial assets [line items]
Financial instrument assets	55	20
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0	(96)
Foreign exchange swaps | Level 1
Disclosure of financial assets [line items]
Financial instrument assets	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0
Foreign exchange swaps | Level 2
Disclosure of financial assets [line items]
Financial instrument assets	55
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0
Foreign exchange swaps | Level 3
Disclosure of financial assets [line items]
Financial instrument assets	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	0
Investments in equity securities
Disclosure of financial assets [line items]
Financial instrument assets	117	$ 159
Investments in equity securities | Level 1
Disclosure of financial assets [line items]
Financial instrument assets	60
Investments in equity securities | Level 2
Disclosure of financial assets [line items]
Financial instrument assets	57
Investments in equity securities | Level 3
Disclosure of financial assets [line items]
Financial instrument assets	$ 0

RISK MANAGEMENT AND FINANCIAL_8

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Financial instruments disclosures Net position) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	$ 46	$ (85)	$ (28)	$ (145)
Less: current portion		(112)
Long-term portion		27
Assets
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	184
Less: current portion	60
Long-term portion	124
Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	138
Less: current portion	27
Long-term portion	111
Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	46
Less: current portion	33
Long-term portion	13
Energy Derivative Contracts
Disclosure of derivative assets liabilities net position [Line Items]
Net Position		(19)
Energy Derivative Contracts | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	3
Energy Derivative Contracts | Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	22
Energy Derivative Contracts | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	(19)
Interest Rate Swaps
Disclosure of derivative assets liabilities net position [Line Items]
Net Position		(149)
Interest Rate Swaps | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	9
Interest Rate Swaps | Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	116
Interest Rate Swaps | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	(107)
Foreign exchange swaps
Disclosure of derivative assets liabilities net position [Line Items]
Net Position		(76)
Foreign exchange swaps | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	55
Foreign exchange swaps | Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	0
Foreign exchange swaps | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	55
Available-for-sale investments
Disclosure of derivative assets liabilities net position [Line Items]
Net Position		$ 159
Available-for-sale investments | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	117
Available-for-sale investments | Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	0
Available-for-sale investments | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Net Position	$ 117

RISK MANAGEMENT AND FINANCIAL_9

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Continuity) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of derivative assets liabilities net position [Line Items]
Balance, beginning of year	$ (85)	$ (28)	$ (145)
Unrealized loss (gain) through income	34	46	(4)
Acquisitions, settlements and other	(44)	89	159
Balance, end of year	46	(85)	(28)
Investments in equity securities
Disclosure of derivative assets liabilities net position [Line Items]
Balance, beginning of year	159
Unrealized (loss) gain through OCI	(16)	(20)	52
Balance, end of year		159
Energy Derivative Contracts
Disclosure of derivative assets liabilities net position [Line Items]
Balance, beginning of year	(19)
Unrealized (loss) gain through OCI	0	(17)	(28)
Unrealized loss (gain) through income	(3)	(5)	0
Balance, end of year		(19)
Interest Rate Swaps
Disclosure of derivative assets liabilities net position [Line Items]
Balance, beginning of year	(149)
Unrealized (loss) gain through OCI	14	18	(1)
Unrealized loss (gain) through income	17	1	(7)
Balance, end of year		(149)
Foreign exchange swaps
Disclosure of derivative assets liabilities net position [Line Items]
Balance, beginning of year	(76)
Unrealized (loss) gain through OCI	87	(94)	(61)
Unrealized loss (gain) through income	$ 76	(29)	$ 3
Balance, end of year		$ (76)

RISK MANAGEMENT AND FINANCIA_10

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Breakdown hedged not hedged) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of financial assets and liabilities [line items]
Financial instrument assets designated at fair value through OCI	$ 136	$ 159	$ 117
Net Position	46	(85)	(28)	$ (145)
Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	35	20	14
Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	32	6	50
Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(89)	(145)	(11)
Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(49)	(125)	(217)
Investments in equity securities
Disclosure of financial assets and liabilities [line items]
Net Position		159
Energy Derivative Contracts
Disclosure of financial assets and liabilities [line items]
Net Position		(19)
Energy Derivative Contracts | Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	3	0	3
Energy Derivative Contracts | Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	0	0	5
Energy Derivative Contracts | Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(7)	(5)	(3)
Energy Derivative Contracts | Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(15)	(14)	(2)
Interest Rate Swaps
Disclosure of financial assets and liabilities [line items]
Net Position		(149)
Interest Rate Swaps | Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	0	1	1
Interest Rate Swaps | Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	9	5	6
Interest Rate Swaps | Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(82)	(107)	(2)
Interest Rate Swaps | Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(34)	(48)	(176)
Foreign exchange swaps
Disclosure of financial assets and liabilities [line items]
Net Position		(76)
Foreign exchange swaps | Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	32	19	10
Foreign exchange swaps | Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	23	1	39
Foreign exchange swaps | Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	0	(33)	(6)
Foreign exchange swaps | Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	$ 0	$ (63)	$ (39)

RISK MANAGEMENT AND FINANCIA_11

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Explanation) € in Millions, £ in Millions, $ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2018CAD ($)	Dec. 31, 2018COP ($)	Dec. 31, 2018EUR (€)	Dec. 31, 2018GBP (£)	Dec. 31, 2018USD ($)	Dec. 31, 2018GW	Dec. 31, 2018	Dec. 31, 2018$ / MWh	Dec. 31, 2018$ / shares	Dec. 31, 2018€ / shares	Dec. 31, 2018£ / shares
Disclosure of risk management strategy related to hedge accounting [line items]
Realized and reclassified from OCI to revenues in the consolidated statements of income (loss)	$ 18,000,000	$ (1,000,000)	$ (41,000,000)
Notional amount		2,557,000,000	9,285,000,000					$ 2,340,000,000
Energy Derivative Contracts
Disclosure of risk management strategy related to hedge accounting [line items]
Realized and reclassified from OCI to revenues in the consolidated statements of income (loss)	6,000,000	23,000,000	48,000,000
Gain (loss) recorded in AOCI expected to be reclassed in the next twelve months in net income	14,000,000	9,000,000	6,000,000
Carrying amount (asset/(liability))	$ (15,000,000)
Notional amount								188,000,000
Notional amount - GWh | GW									5,024
Weighted average hedged rate for the year | $ / MWh											37
Maturity dates	Jan 2019 - Dec 2020
Hedge ratio	1:1
Change in discounted spot value of outstanding hedging instruments								(8,000,000)
Change in value of hedged item used to determine hedge effectiveness	$ 9,000,000
Hedge ineffectiveness loss recognized in Unrealized financial instruments loss in the consolidated statements of income	2,000,000
Interest Rate Swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Realized and reclassified from OCI to revenues in the consolidated statements of income (loss)	14,000,000	20,000,000	16,000,000
Gain (loss) recorded in AOCI expected to be reclassed in the next twelve months in net income	10,000,000	$ 18,000,000	110,000,000
Carrying amount (asset/(liability))	$ (25,000,000)
Notional amount				$ 151	$ 256			178,000,000
Maturity dates	Aug 2019 - Sep 2036
Hedge ratio	1:1
Change in discounted spot value of outstanding hedging instruments								8,000,000
Change in value of hedged item used to determine hedge effectiveness	$ (2,000,000)
Derivative, Weighted Average Fixed interest rate		4.50%								3.60%
Hedge ineffectiveness loss recognized in Unrealized financial instruments loss in the consolidated statements of income	9,000,000
Interest Rate Swaps | Designated as Hedging Instrument
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount		$ 1,704,000,000						1,444,000,000
Interest Rate Swaps | Not Designated as Hedging Instrument
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount		780,000,000						383,000,000
Foreign exchange swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Gain (loss) recorded in AOCI expected to be reclassed in the next twelve months in net income		48,000,000	1,000,000
Carrying amount (asset/(liability))	$ 23,000,000
Notional amount				$ 419		€ 221	£ 247	0
Weighted average hedged rate for the year												1.34	0.82	0.76
Maturity dates	Jan 2019 - Dec 2019
Hedge ratio	1:1
Foreign exchange swaps | Designated as Hedging Instrument
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount		2,306,000,000						1,844,000,000
Foreign exchange swaps | Not Designated as Hedging Instrument
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount		718,000,000						957,000,000
Investments in equity securities
Disclosure of risk management strategy related to hedge accounting [line items]
Realized and reclassified from OCI to revenues in the consolidated statements of income (loss)		2,000,000	$ 9,000,000
Notional amount		$ 15,000,000						$ 4,000,000

RISK MANAGEMENT AND FINANCIA_12

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Equity reservers impacted by financial instruments) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of risk management strategy related to hedge accounting [line items]
Balance, as at	$ 2,557	$ 9,285
Change in Effective portion of Fair Value Hedges	34	46	$ (4)
Balance, as at	2,340	2,557	$ 9,285
Cash Flow Hedges
Disclosure of risk management strategy related to hedge accounting [line items]
Balance, as at	(29)
Amount reclassified to profit or loss	7
Foreign currency revaluation of CAD borrowings	0
Foreign currency revaluation of net foreign operations	0
Valuation of investments in equity securities designated FVOCI	0
Tax Effect	(2)
Other	(10)
Balance, as at	(34)	(29)
Cash Flow Hedges | Energy Derivative Contracts [Member]
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	(1)
Cash Flow Hedges | Interest Rate Swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	1
Cash Flow Hedges | Foreign exchange swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	0
Investments in equity securities
Disclosure of risk management strategy related to hedge accounting [line items]
Balance, as at	15
Amount reclassified to profit or loss	0
Foreign currency revaluation of CAD borrowings	0
Foreign currency revaluation of net foreign operations	0
Valuation of investments in equity securities designated FVOCI	(8)
Tax Effect	0
Other	(3)
Balance, as at	4	15
Investments in equity securities | Energy Derivative Contracts [Member]
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	0
Investments in equity securities | Interest Rate Swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	0
Investments in equity securities | Foreign exchange swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	0
Foreign Currency Translation
Disclosure of risk management strategy related to hedge accounting [line items]
Balance, as at	(378)
Amount reclassified to profit or loss	0
Foreign currency revaluation of CAD borrowings	87
Foreign currency revaluation of net foreign operations	(324)
Valuation of investments in equity securities designated FVOCI	0
Tax Effect	(10)
Other	(69)
Balance, as at	(652)	$ (378)
Foreign Currency Translation | Energy Derivative Contracts [Member]
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	0
Foreign Currency Translation | Interest Rate Swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	0
Foreign Currency Translation | Foreign exchange swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Change in Effective portion of Fair Value Hedges	$ 42

SEGMENTED INFORMATION (Details

SEGMENTED INFORMATION (Details - FFO reconciliation) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of operating segments [line items]
Revenues	$ 2,982	$ 2,625	$ 2,452
Other income	50	47	64
Direct operating costs	(1,036)	(978)	(1,038)
Share of Adjusted EBITDA from equity accounted investments	130	29	9
Adjusted EBITDA	0	0
Management service costs	(80)	(82)	(62)
Interest expense borrowings	(705)	(632)	(606)
Current income taxes	30	39	44
Distributions to preferred limited partners equity	(38)	(28)
Distributions attributable to preferred equity	(26)	(26)
Share of interest and cash taxes from equity accounted investments	(97)	(22)
Share of Funds From Operations attributable to non-controlling interests	(571)	(341)
Funds From Operations	0	0
Depreciation	(819)	(782)	(781)
Foreign exchange and unrealized financial instruments (loss) gain	34	46	(4)
Deferred income tax (recovery) expense	89	(49)	97
Other	(82)	(15)	(46)
Share of earnings from equity accounted investments	(62)	(27)	(9)
Net income	274	288	65
Net Income Loss Attributable To Unit Holders	42	(56)
Net income attributable to participating non-controlling interests	297	53	65
Brazil
Disclosure of operating segments [line items]
Revenues	429	366	269
Colombia
Disclosure of operating segments [line items]
Revenues	896	797	819
Asia
Disclosure of operating segments [line items]
Revenues	177	0	0
Europe
Disclosure of operating segments [line items]
Revenues	126	111	136
Attributable to Unitholders
Disclosure of operating segments [line items]
Revenues	1,930	1,679	1,481
Other income	46	40	47
Direct operating costs	(653)	(577)	(586)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	1,323	1,142	942
Management service costs	(80)	(82)	(62)
Interest expense borrowings	(486)	(407)	(402)
Current income taxes	(17)	(18)	(19)
Distributions to preferred limited partners equity	(38)	(28)	(15)
Distributions attributable to preferred equity	(26)	(26)	(25)
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	676	581	419
Depreciation	(630)	(539)	(540)
Foreign exchange and unrealized financial instruments (loss) gain	(2)	(47)	4
Deferred income tax (recovery) expense	85	(25)	78
Other	(87)	(26)	(26)
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	42	(56)	(65)
Attributable to Unitholders | Hydroelectric | North America
Disclosure of operating segments [line items]
Revenues	893	945	819
Other income	12	1	24
Direct operating costs	(286)	(281)	(295)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	619	665	548
Management service costs	0	0	0
Interest expense borrowings	(172)	(180)	(177)
Current income taxes	(4)	1	(4)
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	443	486	367
Depreciation	(231)	(220)	(244)
Foreign exchange and unrealized financial instruments (loss) gain	(1)	(12)	1
Deferred income tax (recovery) expense	(1)	(67)	31
Other	(21)	(17)	(27)
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	189	170	128
Attributable to Unitholders | Hydroelectric | Brazil
Disclosure of operating segments [line items]
Revenues	244	243	187
Other income	5	12	13
Direct operating costs	(76)	(77)	(70)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	173	178	130
Management service costs	0	0	0
Interest expense borrowings	(22)	(18)	(24)
Current income taxes	(9)	(12)	(9)
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	142	148	97
Depreciation	(136)	(142)	(125)
Foreign exchange and unrealized financial instruments (loss) gain	(1)	(3)	0
Deferred income tax (recovery) expense	1	2	7
Other	(3)	(8)	(5)
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	3	(3)	(26)
Attributable to Unitholders | Hydroelectric | Colombia
Disclosure of operating segments [line items]
Revenues	216	191	192
Other income	4	2	3
Direct operating costs	(94)	(94)	(107)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	126	99	88
Management service costs	0	0	0
Interest expense borrowings	(38)	(42)	(36)
Current income taxes	(2)	(5)	(6)
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	86	52	46
Depreciation	(18)	(26)	(31)
Foreign exchange and unrealized financial instruments (loss) gain	7	(3)	1
Deferred income tax (recovery) expense	18	(10)	6
Other	(6)	6	3
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	87	19	25
Attributable to Unitholders | Wind | North America
Disclosure of operating segments [line items]
Revenues	219	161	151
Other income	2	0	0
Direct operating costs	(64)	(42)	(36)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	157	119	115
Management service costs	0	0	0
Interest expense borrowings	(63)	(45)	(41)
Current income taxes	(1)	0	0
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	93	74	74
Depreciation	(122)	(90)	(80)
Foreign exchange and unrealized financial instruments (loss) gain	2	1	0
Deferred income tax (recovery) expense	20	28	49
Other	(11)	(4)	4
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	(18)	9	47
Attributable to Unitholders | Wind | Brazil
Disclosure of operating segments [line items]
Revenues	42	26	56
Other income	0	0	0
Direct operating costs	(9)	(4)	(24)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	33	22	32
Management service costs	0	0	0
Interest expense borrowings	(9)	(6)	(14)
Current income taxes	0	0	0
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	24	16	18
Depreciation	(13)	(7)	(38)
Foreign exchange and unrealized financial instruments (loss) gain	(10)	0	0
Deferred income tax (recovery) expense	0	0	6
Other	0	2	6
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	1	11	(8)
Attributable to Unitholders | Wind | Asia
Disclosure of operating segments [line items]
Revenues	12
Other income	0
Direct operating costs	(4)
Share of Adjusted EBITDA from equity accounted investments	0
Adjusted EBITDA	8
Management service costs	0
Interest expense borrowings	(4)
Current income taxes	1
Distributions to preferred limited partners equity	0
Distributions attributable to preferred equity	0
Share of interest and cash taxes from equity accounted investments	0
Share of Funds From Operations attributable to non-controlling interests	0
Funds From Operations	5
Depreciation	(2)
Foreign exchange and unrealized financial instruments (loss) gain	3
Deferred income tax (recovery) expense	0
Other	(2)
Share of earnings from equity accounted investments	0
Net income	0
Net Income Loss Attributable To Unit Holders	4
Attributable to Unitholders | Wind | Europe
Disclosure of operating segments [line items]
Revenues	73	46	17
Other income	11	0	0
Direct operating costs	(27)	(20)	(4)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	57	26	13
Management service costs	0	0	0
Interest expense borrowings	(17)	(10)	(7)
Current income taxes	(2)	(1)	0
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	38	15	6
Depreciation	(43)	(25)	(4)
Foreign exchange and unrealized financial instruments (loss) gain	9	(14)	0
Deferred income tax (recovery) expense	2	5	0
Other	(1)	4	(1)
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	5	(15)	1
Attributable to Unitholders | Solar
Disclosure of operating segments [line items]
Revenues	146
Other income	5
Direct operating costs	(34)
Share of Adjusted EBITDA from equity accounted investments	0
Adjusted EBITDA	117
Management service costs	0
Interest expense borrowings	(45)
Current income taxes	0
Distributions to preferred limited partners equity	0
Distributions attributable to preferred equity	0
Share of interest and cash taxes from equity accounted investments	0
Share of Funds From Operations attributable to non-controlling interests	0
Funds From Operations	72
Depreciation	(40)
Foreign exchange and unrealized financial instruments (loss) gain	(9)
Deferred income tax (recovery) expense	21
Other	(11)
Share of earnings from equity accounted investments	0
Net income	0
Net Income Loss Attributable To Unit Holders	33
Attributable to Unitholders | Storage and Other
Disclosure of operating segments [line items]
Revenues	85	59	58
Other income	0	6	(1)
Direct operating costs	(36)	(32)	(26)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	49	33	31
Management service costs	0	0	0
Interest expense borrowings	(17)	(14)	(12)
Current income taxes	0	0	0
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	32	19	19
Depreciation	(23)	(25)	(18)
Foreign exchange and unrealized financial instruments (loss) gain	(2)	0	2
Deferred income tax (recovery) expense	0	0	0
Other	(9)	0	(2)
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	(2)	(6)	1
Attributable to Unitholders | Corporate
Disclosure of operating segments [line items]
Revenues	0	0	1
Other income	7	19	8
Direct operating costs	(23)	(25)	(24)
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Adjusted EBITDA	(16)	(6)	(15)
Management service costs	(80)	(82)	(62)
Interest expense borrowings	(99)	(89)	(91)
Current income taxes	0	0	0
Distributions to preferred limited partners equity	(38)	(28)	(15)
Distributions attributable to preferred equity	(26)	(26)	(25)
Share of interest and cash taxes from equity accounted investments	0	0	0
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	(259)	(231)	(208)
Depreciation	(2)	0	0
Foreign exchange and unrealized financial instruments (loss) gain	0	(15)	0
Deferred income tax (recovery) expense	24	16	(21)
Other	(23)	(6)	(4)
Share of earnings from equity accounted investments	0	0	0
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	(260)	(236)	(233)
Contribution from equity accounted investments
Disclosure of operating segments [line items]
Revenues	(286)	(74)	(37)
Other income	(7)	(11)	0
Direct operating costs	86	28	16
Share of Adjusted EBITDA from equity accounted investments	207	57	21
Adjusted EBITDA	0	0	0
Management service costs	0	0	0
Interest expense borrowings	82	21	12
Current income taxes	3	1	0
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	(85)	(22)	(12)
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	0	0	0
Depreciation	96	22	11
Foreign exchange and unrealized financial instruments (loss) gain	(3)	2	0
Deferred income tax (recovery) expense	(50)	(3)	0
Other	19	12	(2)
Share of earnings from equity accounted investments	(62)	(33)	(9)
Net income	0	0	0
Net Income Loss Attributable To Unit Holders	0	0	0
Attributable to non-controlling interests
Disclosure of operating segments [line items]
Revenues	1,338	1,020	1,008
Other income	11	18	17
Direct operating costs	(469)	(429)	(468)
Share of Adjusted EBITDA from equity accounted investments	20	0	0
Adjusted EBITDA	900	609	557
Management service costs	0	0	0
Interest expense borrowings	(301)	(246)	(216)
Current income taxes	(16)	(22)	(25)
Distributions to preferred limited partners equity	0	0	0
Distributions attributable to preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	(12)	0	0
Share of Funds From Operations attributable to non-controlling interests	(571)	(341)	(316)
Funds From Operations	0	0	0
Depreciation	(285)	(265)	(252)
Foreign exchange and unrealized financial instruments (loss) gain	(29)	(1)	0
Deferred income tax (recovery) expense	54	(21)	19
Other	(14)	(1)	(18)
Share of earnings from equity accounted investments	0	0	0
Net income	274	288	251
Net Income Loss Attributable To Unit Holders	0	0	0
As per IFRS Financials
Disclosure of operating segments [line items]
Revenues	2,982	2,625	2,452
Other income	50	47	64
Direct operating costs	(1,036)	(978)	(1,038)
Share of Adjusted EBITDA from equity accounted investments	227	57	21
Adjusted EBITDA	0	0	0
Management service costs	(80)	(82)	(62)
Interest expense borrowings	(705)	(632)	(606)
Current income taxes	(30)	(39)	(44)
Distributions to preferred limited partners equity	(38)	(28)	(15)
Distributions attributable to preferred equity	(26)	(26)	(25)
Share of interest and cash taxes from equity accounted investments	(97)	(22)	(12)
Share of Funds From Operations attributable to non-controlling interests	(571)	(341)	(316)
Funds From Operations	0	0	0
Depreciation	(819)	(782)	(781)
Foreign exchange and unrealized financial instruments (loss) gain	(34)	(46)	4
Deferred income tax (recovery) expense	89	(49)	97
Other	(82)	(15)	(46)
Share of earnings from equity accounted investments	(62)	(33)	(9)
Net income	274	288	251
Net Income Loss Attributable To Unit Holders	$ 42	$ (56)	$ (65)

SEGMENTED INFORMATION (Detail_2

SEGMENTED INFORMATION (Details - Balance Sheet) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of operating segments [line items]
Cash and cash equivalents	$ 173	$ 799	$ 223	$ 63
Property, plant and equipment, at fair value	29,025	27,096	25,257	18,358
Total assets	34,103	30,904
Total borrowings	10,718		11,766	10,182
Total liabilities	16,897	16,622
Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	169	330
Property, plant and equipment, at fair value	20,728	18,429
Total assets	22,583	19,962
Total borrowings	8,989	8,439
Total liabilities	4,515	3,540
For the year ended December 31: Additions to Property Plant and Equipment	172	220
Contribution from equity accounted investments
Disclosure of operating segments [line items]
Cash and cash equivalents	(81)	(30)
Property, plant and equipment, at fair value	(3,529)	(1,451)
Total assets	(2,483)	(1,040)
Total borrowings	(1,972)	(848)
Total liabilities	(511)	(191)
For the year ended December 31: Additions to Property Plant and Equipment	(16)	(10)
Attributable to non-controlling interests
Disclosure of operating segments [line items]
Cash and cash equivalents	85	499
Property, plant and equipment, at fair value	11,826	10,118
Total assets	14,003	11,982
Total borrowings	3,701	4,175
Total liabilities	2,175	1,507
For the year ended December 31: Additions to Property Plant and Equipment	145	144
As per IFRS Financials
Disclosure of operating segments [line items]
Cash and cash equivalents	173	799
Property, plant and equipment, at fair value	29,025	27,096
Total assets	34,103	30,904
Total borrowings	10,718	11,766
Total liabilities	6,179	4,856
For the year ended December 31: Additions to Property Plant and Equipment	301	354
Hydroelectric
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	24,679	22,399	21,569	14,847
Hydroelectric | North America | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	6	21
Property, plant and equipment, at fair value	11,498	11,396
Total assets	12,125	11,709
Total borrowings	2,995	3,049
Total liabilities	2,764	2,188
For the year ended December 31: Additions to Property Plant and Equipment	96	90
Hydroelectric | Colombia | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	7	14
Property, plant and equipment, at fair value	1,609	1,303
Total assets	1,868	1,574
Total borrowings	419	447
Total liabilities	434	354
For the year ended December 31: Additions to Property Plant and Equipment	7	8
Hydroelectric | Brazil | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	37	40
Property, plant and equipment, at fair value	1,907	1,908
Total assets	2,105	2,149
Total borrowings	198	200
Total liabilities	150	180
For the year ended December 31: Additions to Property Plant and Equipment	30	59
Wind
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	3,860	3,803	3,313	3,233
Wind | North America | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	30	18
Property, plant and equipment, at fair value	2,480	1,798
Total assets	2,554	1,888
Total borrowings	1,204	1,005
Total liabilities	536	333
For the year ended December 31: Additions to Property Plant and Equipment	11	6
Wind | Colombia | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	29	19
Property, plant and equipment, at fair value	819	482
Total assets	939	532
Total borrowings	463	233
Total liabilities	124	101
For the year ended December 31: Additions to Property Plant and Equipment	10	34
Wind | Brazil | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	5	7
Property, plant and equipment, at fair value	348	304
Total assets	379	443
Total borrowings	75	192
Total liabilities	7	16
For the year ended December 31: Additions to Property Plant and Equipment	0	0
Wind | Asia | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	2	103
Property, plant and equipment, at fair value	36	11
Total assets	56	31
Total borrowings	31	9
Total liabilities	3	9
For the year ended December 31: Additions to Property Plant and Equipment	0	0
Solar
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	228	575	$ 0	$ 0
Solar | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	41	90
Property, plant and equipment, at fair value	1,354	602
Total assets	1,650	765
Total borrowings	1,021	499
Total liabilities	255	74
For the year ended December 31: Additions to Property Plant and Equipment	9	0
Storage and Other | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	9	11
Property, plant and equipment, at fair value	686	625
Total assets	746	691
Total borrowings	249	253
Total liabilities	31	51
For the year ended December 31: Additions to Property Plant and Equipment	3	13
Corporate | Attributable to Unitholders
Disclosure of operating segments [line items]
Cash and cash equivalents	3	7
Property, plant and equipment, at fair value	(9)	0
Total assets	161	180
Total borrowings	2,334	2,552
Total liabilities	211	234
For the year ended December 31: Additions to Property Plant and Equipment	$ 6	$ 10

SEGMENTED INFORMATION (Detail_3

SEGMENTED INFORMATION (Details - Geographical Information) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of operating segments [line items]
Revenues	$ 2,982	$ 2,625	$ 2,452
Consolidated property, plant and equipment and equity-accounted investments	30,594	27,817
United States
Disclosure of operating segments [line items]
Revenues	926	871	786
Consolidated property, plant and equipment and equity-accounted investments	12,705	11,131
Colombia
Disclosure of operating segments [line items]
Revenues	896	797	819
Consolidated property, plant and equipment and equity-accounted investments	6,665	5,401
Canada
Disclosure of operating segments [line items]
Revenues	428	480	442
Consolidated property, plant and equipment and equity-accounted investments	5,705	5,810
Brazil
Disclosure of operating segments [line items]
Revenues	429	366	269
Consolidated property, plant and equipment and equity-accounted investments	3,553	3,479
Europe
Disclosure of operating segments [line items]
Revenues	126	111	136
Consolidated property, plant and equipment and equity-accounted investments	1,624	1,332
Asia
Disclosure of operating segments [line items]
Revenues	177	0	$ 0
Consolidated property, plant and equipment and equity-accounted investments	$ 342	$ 664

OTHER INCOME (Details)

OTHER INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Other income [line items]
Interest income and other	$ 22	$ 32	$ 41
Gain on available for sale investments	0	15	0
Gains on settlement of foreign currency contracts	28	0	23
Other Income, net	$ 50	$ 47	$ 64

DIRECT OPERATING COSTS (Details

DIRECT OPERATING COSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure Direct Operating Costs [Abstract]
Operations, maintenance and administration	$ 581	$ 567	$ 553
Water royalties, property taxes and other	142	161	149
Fuel and power purchases	289	226	313
Energy marketing fees	24	24	23
Direct operating costs, net	$ 1,036	$ 978	$ 1,038

OTHER (Details)

OTHER (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure Other [Abstract]
Transaction costs	$ 2	$ 9	$ 22
Change in fair value of property, plant and equipment	44	33	36
Other	36	(27)	(12)
Other expenses, net	$ 82	$ 15	$ 46

FOREIGN CURRENCY TRANSLATION (D

FOREIGN CURRENCY TRANSLATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Foreign currency translation on
Property, plant and equipment, at fair value	$ (1,512)	$ 506	$ 1,186
Long-term debt and credit facilities	537	(282)	(244)
Deferred income tax liabilities and assets	184	(82)	(157)
Other assets and liabilities	(34)	48	201
Foreign currency translation, net	$ (825)	$ 190	$ 986

INCOME TAXES (Details - Compone

INCOME TAXES (Details - Components of tax PL) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current tax expense (income) and adjustments for current tax of prior periods [abstract]
Current	$ (30)	$ (39)	$ (44)
Income tax (expense) recovery
Income taxes - origination and reversal of temporary differences	2	8	71
Relating to change in tax rates / imposition of new tax laws	95	(42)	35
Relating to unrecognized temporary differences and tax losses	(8)	(15)	(9)
Deferred taxes, net	89	(49)	97
Total Income Tax recovery (expense)	$ 59	$ (88)	$ 53

INCOME TAXES (Details - Compo_2

INCOME TAXES (Details - Components of tax OCI) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Deferred income tax attributed to
Financial instruments designated as cash flow hedges	$ (2)	$ (4)	$ 2
Other components of deferred tax expense (income)	(20)	15	(7)
Revaluation surplus
Origination and reversal of temporary differences	(1,117)	(248)	(55)
Income tax relating to changes in revaluation surplus of other comprehensive income for tax rate changes or imposition of new taxes	54	586	19
Total deferred income taxes	$ (1,085)	$ 349	$ (41)

INCOME TAXES (Details - Expense

INCOME TAXES (Details - Expense reconciliation) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Effective income tax [abstract]
Statutory income tax (expense) recovery	$ (100)	$ (50)	$ 5
(Reduction) increase resulting from
Increase decrease in tax assets not recognised	(8)	(15)	(9)
Deemed profit method difference in Brazil	0	0	0
Differences between statutory rate and future tax rate	(95)	37	(43)
Income or losses recorded not taxable to Brookfield Renewable	75	14	14
Other	(3)	0	0
Total Income Tax recovery (expense)	$ 59	$ (88)	$ 53
Effective income tax rate	(17.15%)	63.31%

INCOME TAXES (Details - Unrecog

INCOME TAXES (Details - Unrecognized deferred tax) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of deductible temporary differences for which no deferred tax asset is recognised [line items]
Unrecognized deferred tax assets	$ 88	$ 116	$ 98
2019 to 2023
Disclosure of deductible temporary differences for which no deferred tax asset is recognised [line items]
Unrecognized deferred tax assets	3	8	0
2024 and Thereafter
Disclosure of deductible temporary differences for which no deferred tax asset is recognised [line items]
Unrecognized deferred tax assets	$ 85	$ 108	$ 98

INCOME TAXES (Details - Reconci

INCOME TAXES (Details - Reconciliation net labilities) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Deferred tax assets and liabilities [line items]
Recognized in Net income (loss)	$ 89	$ (49)	$ 97
Foreign exchange	184	(82)	(157)
Balance, end of year	27
Deferred tax liability related to property, plant and equipment revaluations	3,685	2,561
The taxable temporary difference attributable to Brookfield Renewables interest in its subsidiaries	3,398	1,549
Noncapital losses
Deferred tax assets and liabilities [line items]
Balance, beginning of year	508	499	458
Recognized in Net income (loss)	(60)	(97)	24
Recognized in equity	1	13	17
Business combination	0	79	0
Foreign exchange	(20)	14	0
Balance, end of year	429	508	499
Amount available for future deductions
Deferred tax assets and liabilities [line items]
Balance, beginning of year	0	0	0
Recognized in Net income (loss)	0	0	0
Recognized in equity	0	0	0
Business combination	0	0	0
Foreign exchange	0	0	0
Balance, end of year	0	0	0
Difference between tax and carrying value
Deferred tax assets and liabilities [line items]
Balance, beginning of year	(3,919)	(4,151)	(2,996)
Recognized in Net income (loss)	149	48	73
Recognized in equity	(985)	341	(48)
Business combination	73	(63)	(1,020)
Foreign exchange	204	(94)	(160)
Balance, end of year	(4,478)	(3,919)	(4,151)
Deferred tax liability asset
Deferred tax assets and liabilities [line items]
Balance, beginning of year	(3,411)	(3,652)	(2,538)
Recognized in Net income (loss)	89	(49)	97
Recognized in equity	(984)	354	(31)
Business combination	73	16	(1,020)
Foreign exchange	184	(80)	(160)
Balance, end of year	$ (4,049)	$ (3,411)	$ (3,652)

PROPERTY, PLANT AND EQUIPMENT_3

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Continuity) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1	$ 27,096	$ 25,257	$ 18,358
Additions	301	354	358
Acquisitions through business combinations	211	1,245	5,741
Disposals property plant and equipment	(61)	(338)
Items recognized through OCI
Change in fair value	4,558	887	431
Foreign exchange	(1,512)	506	1,186
Items recognized through net income
Change in fair value	(61)	(33)	(36)
Depreciation	(819)	(782)	(781)
Balance, as at Dec 31	29,025	27,096	25,257
Other intangible assets	11	13
Construction in progress	388	601
Hydroelectric
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1	22,399	21,569	14,847
Additions	212	253	269
Acquisitions through business combinations	0	0	5,731
Disposals property plant and equipment	(33)	0
Items recognized through OCI
Change in fair value	3,775	828	190
Foreign exchange	(1,138)	332	1,114
Items recognized through net income
Change in fair value	(33)	(20)	(17)
Depreciation	(536)	(563)	(565)
Balance, as at Dec 31	24,679	22,399	21,569
Wind
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1	3,803	3,313	3,233
Additions	36	95	71
Acquisitions through business combinations	125	670	10
Disposals property plant and equipment	(20)	(338)
Items recognized through OCI
Change in fair value	466	91	187
Foreign exchange	(256)	177	21
Items recognized through net income
Change in fair value	(20)	(8)	(10)
Depreciation	(236)	(197)	(199)
Balance, as at Dec 31	3,860	3,803	3,313
Solar
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1	575	0	0
Additions	47	0	0
Acquisitions through business combinations	86	575	0
Disposals property plant and equipment	(691)	0
Items recognized through OCI
Change in fair value	313	0	0
Foreign exchange	(77)	0	0
Items recognized through net income
Change in fair value	0	0	0
Depreciation	(25)	0	0
Balance, as at Dec 31	228	575	0
Other
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1	319	375	278
Additions	6	6	18
Acquisitions through business combinations	0	0	0
Disposals property plant and equipment	(8)	0
Items recognized through OCI
Change in fair value	4	(32)	54
Foreign exchange	(41)	(3)	51
Items recognized through net income
Change in fair value	(8)	(5)	(9)
Depreciation	(22)	(22)	(17)
Balance, as at Dec 31	$ 258	$ 319	$ 375

PROPERTY, PLANT AND EQUIPMENT_4

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Rates)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2018
North America
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Exit date	2,037
North America | Bottom of range
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Terminal capitalization rate	6.20%	6.10%
North America | Bottom of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	4.90%	4.80%
North America | Bottom of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	6.50%	6.40%
North America | Top of range
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Terminal capitalization rate	7.50%	7.10%
North America | Top of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	6.00%	5.60%
North America | Top of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	7.60%	7.20%
Colombia
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Exit date	2,037
Colombia | Top of range
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Terminal capitalization rate	12.60%	10.40%
Colombia | Top of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	11.30%	9.60%
Colombia | Top of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	12.60%	10.90%
Brazil
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Exit date	2,032
Brazil | Top of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	8.90%	9.00%
Brazil | Top of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	10.20%	10.30%
Europe
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Exit date	2,031
Europe | Bottom of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	410.00%	400.00%
Europe | Bottom of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	590.00%	580.00%
Europe | Top of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	450.00%	430.00%
Europe | Top of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	630.00%	610.00%

PROPERTY, PLANT AND EQUIPMENT_5

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Sensitivity) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Changes in Property Plant And Equipment [Line Items]
Change in fair value	$ 4,558	$ 887	$ 431
Hydroelectric
Changes in Property Plant And Equipment [Line Items]
Change in fair value	3,775	828	$ 190
Impact Of 5% Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	1,290	1,020
Impact Of 5% Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(1,290)	(1,020)
25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(1,050)	(910)
25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(240)	(200)
25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	1,130	970
25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	260	210
North America | Impact Of 5% Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	800	620
North America | Impact Of 5% Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(800)	(620)
North America | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(770)	(710)
North America | 25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(210)	(180)
North America | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	840	770
North America | 25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	$ 230	$ 190
Brazil | Hydroelectric
Changes in Property Plant And Equipment [Line Items]
Useful life	29	15
Brazil | Impact Of 5% Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	$ 370	$ 310
Brazil | Impact Of 5% Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(370)	(310)
Brazil | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(180)	(130)
Brazil | 25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(30)	(20)
Brazil | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	190	130
Brazil | 25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	30	20
Colombia | Impact Of 5% Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	100	70
Colombia | Impact Of 5% Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(100)	(70)
Colombia | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(80)	(50)
Colombia | 25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	0	0
Colombia | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	80	50
Colombia | 25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	0	0
Europe | Impact Of 5% Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	20	20
Europe | Impact Of 5% Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(20)	(20)
Europe | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	(20)	(20)
Europe | 25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	0	0
Europe | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	20	20
Europe | 25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Change in fair value	$ 0	$ 0

PROPERTY, PLANT AND EQUIPMENT_6

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Prices and Generation) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)$ / MWh$ / MWh€ / MWhR$ / MWh	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Change in fair value | $	$ 4,558	$ 887	$ 431
Brookfield Renewable
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Change in fair value | $	$ 160	$ 150
North America | 1-10 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements	83
Estimates of future electricity prices	68
North America | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	57.00%
North America | 11-20 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements	80
Estimates of future electricity prices	116
North America | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	34.00%
Colombia | 1-10 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements	201,000
Estimates of future electricity prices	252,000
Colombia | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	22.00%
Colombia | 11-20 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements	0
Estimates of future electricity prices	354,000
Colombia | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	0.00%
Brazil | 1-10 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements | R$ / MWh	286
Estimates of future electricity prices | R$ / MWh	287
Brazil | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	69.00%
Brazil | 11-20 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements | R$ / MWh	397
Estimates of future electricity prices | R$ / MWh	452
Brazil | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	35.00%
Europe | 1-10 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements | € / MWh	93
Estimates of future electricity prices | € / MWh	79
Europe | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	72.00%
Europe | 11-20 years
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Power prices from long-term power purchase agreements | € / MWh	111
Estimates of future electricity prices | € / MWh	92
Europe | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of total generation contracted	25.00%

PROPERTY, PLANT AND EQUIPMENT_7

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Historical costs) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	$ 16,703	$ 15,147	$ 16,703
Hydroelectric
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	11,888	12,740
Wind
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	2,753	3,030
Solar
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	260	621
Other
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	$ 246	$ 312

BORROWINGS (Details - Corporate

BORROWINGS (Details - Corporate Borrowings - Composition of corporate borrowings) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Detailed Information About Borrowings
Carrying Value	$ 2,340	$ 2,557	$ 9,285
Total	2,328	2,393
Less: Unamortized financing fees				$ 80
Less: Current portion	6	159
Long-term debt and credit facilities	10,718		11,766	10,182
Corporate Borrowings
Detailed Information About Borrowings
Total	2,340	2,557
Less: Unamortized financing fees	(6)	(5)	5	6
Less: Current portion	(6)	(159)
Long-term debt and credit facilities	2,328	2,393
Corporate Borrowings | At fair value
Detailed Information About Borrowings
Total	$ 2,367	$ 2,641
Credit facilities
Detailed Information About Borrowings
Weighted Average Interest Rate	3.30%	2.60%
Weighted Average Borrowings Term	4.4	4.5
Carrying Value	$ 727	$ 887
Estimated fair value	727	887
Long-term debt and credit facilities	201
Medium Term Notes
Detailed Information About Borrowings
Carrying Value	1,613	1,670
Estimated fair value	1,640	1,754
Sudsidiary
Detailed Information About Borrowings
Less: Unamortized financing fees		76	$ 72	$ 74
Series 3 | Medium Term Notes
Detailed Information About Borrowings
Carrying Value	0	159
Estimated fair value	0	163
Series 4 | Medium Term Notes
Detailed Information About Borrowings
Carrying Value	110	119
Estimated fair value	124	144
Series 7 | Medium Term Notes
Detailed Information About Borrowings
Carrying Value	330	358
Estimated fair value	342	382
Series 8 | Medium Term Notes
Detailed Information About Borrowings
Carrying Value	293	318
Estimated fair value	309	344
Series 9 | Medium Term Notes
Detailed Information About Borrowings
Carrying Value	293	318
Estimated fair value	288	321
Series 10 | Medium Term Notes
Detailed Information About Borrowings
Carrying Value	367	398
Estimated fair value	357	400
Series 11 | Medium Term Notes
Detailed Information About Borrowings
Carrying Value	220	0
Estimated fair value	$ 220	$ 0

BORROWINGS (Details - Corpora_2

BORROWINGS (Details - Corporate Borrowings - Change in the unamortized financing fees of corporate borrowings) - Corporate Borrowings - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Detailed Information About Borrowings
Unamortized financing fees, beginning of year	$ 5	$ 6	$ 5
Additional financing fees	2	0	2
Amortization of financing fees	(1)	(1)	(1)
Unamortized financing fees, end of year	$ 6	$ 5	$ 6

BORROWINGS (Details - Corpora_3

BORROWINGS (Details - Corporate Borrowings - Credit Facilities and Medium Term Notes) $ in Millions, $ in Millions	Sep. 20, 2018CAD ($)	Feb. 22, 2018	Dec. 31, 2018USD ($)	Nov. 30, 2018CAD ($)	Nov. 30, 2018USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Sep. 20, 2018USD ($)	Jun. 30, 2018USD ($)	May 31, 2018USD ($)	Dec. 31, 2015USD ($)
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings			$ 10,718			$ 10,718		$ 11,766				$ 10,182
Long-term debt - repayments						3,527	$ 1,607	$ 1,975
Corporate Borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings			2,328			2,328	$ 2,393
Revolving Credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings			$ 201			$ 201
Weighted Average Interest Rate			3.30%			3.30%	2.60%
Weighted Average Borrowings Term			4.4			4.4	4.5
Corporate credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Available portion of corporate credit facilities			$ 1,371			$ 1,371	$ 1,212
Corporate credit facilities | Brookfield Renewable
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings										$ 1,700	$ 300
Weighted Average Interest Rate										1.20%
Unsecured revolving credit facility
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Placed funds on deposit			251			251
Unsecured revolving credit facility | Brookfield Renewable
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings			$ 400			$ 400
Borrowings, maturity			one year to December 2019
Weighted Average Interest Rate			2.00%			2.00%
Placed funds on deposit			$ 200			$ 200
Accured Intested						8	1
Senior Notes
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings, maturity		2,022
Weighted Average Interest Rate		9.75%
Medium Term Notes | Brookfield Renewable
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	$ 300								$ 231
Borrowings, maturity	January 2,029
Weighted Average Interest Rate	4.25%								4.25%
Long-term debt - repayments				$ 200	$ 153
Authorized corporate credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Available portion of corporate credit facilities			2,100			2,100	2,090
Draws on corporate credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Available portion of corporate credit facilities			(721)			(721)	(685)
Issued letters of credit
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Available portion of corporate credit facilities			(8)			(8)	(193)
Subscription facility
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Available portion of corporate credit facilities			$ 6			$ 6	$ 202

BORROWINGS (Details - Non-recou

BORROWINGS (Details - Non-recourse borrowings - Composition of non-recourse borrowings) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Detailed Information About Borrowings
Carrying Value	$ 2,340	$ 2,557	$ 9,285
Total	2,328	2,393
Less: Unamortized financing fees				$ 80
Less: Current portion	489	1,517
Non Recourse Borrowings	7,895	7,697
2,019
Detailed Information About Borrowings
Carrying Value	6	159
Non Recourse Borrowings	489	1,517
Thereafter
Detailed Information About Borrowings
Carrying Value	990	835
Non Recourse Borrowings	$ 5,164	$ 4,744
Non Recourse Borrowings
Detailed Information About Borrowings
Weighted Average Interest Rate	5.70%	6.50%
Weighted Average Borrowings Term	9.5	9
Carrying Value	$ 8,459	$ 9,285
Estimated fair value	8,696	9,838
Total	8,459	9,285
Add: Unamortized premiums	1	1
Less: Unamortized financing fees	(76)	(72)
Less: Current portion	(489)	(1,517)
Non Recourse Borrowings	7,895	$ 7,697
Non Recourse Borrowings | 2019
Detailed Information About Borrowings
Total	489
Non Recourse Borrowings | 2020
Detailed Information About Borrowings
Total	566
Non Recourse Borrowings | 2021
Detailed Information About Borrowings
Total	374
Non Recourse Borrowings | 2022
Detailed Information About Borrowings
Total	620
Non Recourse Borrowings | 2023
Detailed Information About Borrowings
Total	1,246
Non Recourse Borrowings | Thereafter
Detailed Information About Borrowings
Total	$ 5,164
Non Recourse Borrowings | Hydroelectric
Detailed Information About Borrowings
Weighted Average Interest Rate	6.10%	6.30%
Weighted Average Borrowings Term	9.2	8.8
Carrying Value	$ 6,318	$ 6,392
Estimated fair value	6,517	$ 6,813
Total	6,318
Non Recourse Borrowings | Hydroelectric | 2019
Detailed Information About Borrowings
Total	306
Non Recourse Borrowings | Hydroelectric | 2020
Detailed Information About Borrowings
Total	446
Non Recourse Borrowings | Hydroelectric | 2021
Detailed Information About Borrowings
Total	164
Non Recourse Borrowings | Hydroelectric | 2022
Detailed Information About Borrowings
Total	491
Non Recourse Borrowings | Hydroelectric | 2023
Detailed Information About Borrowings
Total	1,084
Non Recourse Borrowings | Hydroelectric | Thereafter
Detailed Information About Borrowings
Total	$ 3,827
Non Recourse Borrowings | Wind
Detailed Information About Borrowings
Weighted Average Interest Rate	4.70%	5.80%
Weighted Average Borrowings Term	10.8	9.7
Carrying Value	$ 1,908	$ 2,211
Estimated fair value	1,951	$ 2,343
Total	1,908
Non Recourse Borrowings | Wind | 2019
Detailed Information About Borrowings
Total	169
Non Recourse Borrowings | Wind | 2020
Detailed Information About Borrowings
Total	119
Non Recourse Borrowings | Wind | 2021
Detailed Information About Borrowings
Total	129
Non Recourse Borrowings | Wind | 2022
Detailed Information About Borrowings
Total	128
Non Recourse Borrowings | Wind | 2023
Detailed Information About Borrowings
Total	161
Non Recourse Borrowings | Wind | Thereafter
Detailed Information About Borrowings
Total	$ 1,202
Non Recourse Borrowings | Solar
Detailed Information About Borrowings
Weighted Average Interest Rate	6.00%	11.10%
Weighted Average Borrowings Term	7.1	7.6
Carrying Value	$ 142	$ 643
Estimated fair value	133	$ 643
Total	142
Non Recourse Borrowings | Solar | 2019
Detailed Information About Borrowings
Total	13
Non Recourse Borrowings | Solar | 2020
Detailed Information About Borrowings
Total	0
Non Recourse Borrowings | Solar | 2021
Detailed Information About Borrowings
Total	4
Non Recourse Borrowings | Solar | 2022
Detailed Information About Borrowings
Total	0
Non Recourse Borrowings | Solar | 2023
Detailed Information About Borrowings
Total	0
Non Recourse Borrowings | Solar | Thereafter
Detailed Information About Borrowings
Total	$ 125
Non Recourse Borrowings | Storage and Other
Detailed Information About Borrowings
Weighted Average Interest Rate	4.00%	8.40%
Weighted Average Borrowings Term	4.9	17.8
Carrying Value	$ 91	$ 39
Estimated fair value	95	39
Total	91
Non Recourse Borrowings | Storage and Other | 2019
Detailed Information About Borrowings
Total	1
Non Recourse Borrowings | Storage and Other | 2020
Detailed Information About Borrowings
Total	1
Non Recourse Borrowings | Storage and Other | 2021
Detailed Information About Borrowings
Total	77
Non Recourse Borrowings | Storage and Other | 2022
Detailed Information About Borrowings
Total	1
Non Recourse Borrowings | Storage and Other | 2023
Detailed Information About Borrowings
Total	1
Non Recourse Borrowings | Storage and Other | Thereafter
Detailed Information About Borrowings
Total	10
Corporate Borrowings
Detailed Information About Borrowings
Total	2,340	2,557
Less: Unamortized financing fees	$ (6)	(5)	5	6
Sudsidiary
Detailed Information About Borrowings
Less: Unamortized financing fees		$ 76	$ 72	$ 74

BORROWINGS (Details - Non-rec_2

BORROWINGS (Details - Non-recourse borrowings - Change in the unamortized financing fees of corporate borrowings) - Non Recourse Borrowings - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Detailed Information About Borrowings
Unamortized financing fees, beginning of year	$ 72	$ 74	$ 54
Additional financing fees	21	16	41
Amortization of financing fees	(12)	(14)	(17)
Foreign exchange translation and other	(5)	(4)	(4)
Unamortized financing fees, end of year	$ 76	$ 72	$ 74

BORROWINGS (Details - Non-rec_3

BORROWINGS (Details - Non-recourse borrowings - Financings during the year) £ in Thousands, $ in Thousands, R$ in Millions, $ in Millions, $ in Millions

Dec. 20, 2018CAD ($)

Dec. 13, 2018

Dec. 11, 2018COP ($)

Nov. 26, 2018COP ($)

Oct. 25, 2018

Sep. 28, 2018

Aug. 31, 2018COP ($)

Apr. 20, 2018BRL (R$)

Feb. 27, 2018COP ($)

Feb. 22, 2018USD ($)

Feb. 15, 2018USD ($)

Jan. 29, 2018BRL (R$)

Jan. 19, 2018GBP (£)

Jan. 16, 2018

Jun. 30, 2018COP ($)

Dec. 31, 2018USD ($)

Dec. 20, 2018USD ($)

Dec. 12, 2018USD ($)

Dec. 11, 2018USD ($)

Nov. 26, 2018USD ($)

Oct. 31, 2018GBP (£)

Oct. 31, 2018USD ($)

Sep. 14, 2018BRL (R$)

Sep. 14, 2018CAD ($)

Sep. 14, 2018USD ($)

Aug. 31, 2018USD ($)

Jun. 30, 2018USD ($)

Apr. 20, 2018USD ($)

Feb. 27, 2018USD ($)

Jan. 29, 2018USD ($)

Jan. 19, 2018USD ($)

Dec. 31, 2017USD ($)

Dec. 31, 2016USD ($)

Detailed Information About Borrowings

Corporate Borrowings

$ 2,340,000

$ 2,557,000

$ 9,285,000

Authorized credit facilities

2,090,000

2.1 GW pumped storage facility | Brookfield Renewable | Non Recourse Borrowings

Detailed Information About Borrowings

Corporate Borrowings

£ 60,000

$ 83,000

Borrowings, maturity

2,021

19 MW hydroelectric facility | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

R$ 130

$ 40,000

Borrowings, maturity

2,038

296 MW hydroelectric facility | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

$ 350,000

Borrowings, maturity

2,033

Borrowings, interest rate

4.50%

LIBOR | 2.1 GW pumped storage facility | Brookfield Renewable | Non Recourse Borrowings

Detailed Information About Borrowings

Borrowings, interest rate

2.75%

2.75%

TJLP | 19 MW hydroelectric facility | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

2.15%

2.15%

Senior Notes

Detailed Information About Borrowings

Borrowings, maturity

2,022

Borrowings, interest rate

9.75%

Repayments of existing principal amount

$ 760,000

Senior Notes | Terraform Global

Detailed Information About Borrowings

Corporate Borrowings

$ 400,000

Borrowings, maturity

March 2,026

Borrowings, interest rate

6.13%

Revolving Credit facilities

Detailed Information About Borrowings

Corporate Borrowings

$ 727,000

$ 887,000

Borrowings, interest rate

3.30%

2.60%

Borrowings Term

4.4

4.5

Revolving Credit facilities | Terraform Global

Detailed Information About Borrowings

Corporate Borrowings

$ 45,000

Borrowings, maturity

February 2,021

Senior unsecured bonds | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

$ 750

$ 262,000

Senior unsecured bonds 1 | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate basis

7

Senior unsecured bonds 1 | CPI | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

7.12%

7.12%

Senior unsecured bonds 2 | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate basis

12

Senior unsecured bonds 2 | CPI | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

3.56%

3.56%

Senior unsecured bonds 3 | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate basis

30

Senior unsecured bonds 3 | CPI | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

3.99%

3.99%

Corporate credit facilities | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

$ 593

$ 186,000

Corporate credit facilities | 2.1 GW pumped storage facility | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

£ 90,000

$ 125,000

Corporate credit facilities | Brazilian hydroelectric business | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

R$ 160

R$ 250

$ 60,000

$ 47,000

Borrowings, maturity

October 2,023

September 2,023

Corporate credit facilities | 166 MW wind portfolio | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

£ 29,000

$ 37,000

$ 60

$ 46,000

Borrowings, maturity

September 2,036

August 2,031

Borrowings, interest rate

4.86%

4.86%

4.86%

Corporate credit facilities | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

$ 250

$ 338

$ 1,762

$ 196,000

$ 77,000

$ 111,000

$ 634,000

Borrowings, maturity

330 days

August 2,025

2,025

Borrowings, interest rate

7.48%

2.97%

7.48%

2.97%

Corporate credit facilities | 377 MW hydroelectric portfolio | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

$ 190,000

Borrowings, maturity

December 2,022

Corporate credit facilities | 488 MW hydroelectric portfolio | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

$ 150

$ 111,000

Borrowings, maturity

November 2,020

Corporate credit facilities | 351 MW hydroelectric portfolio | Brookfield Renewable

Detailed Information About Borrowings

Corporate Borrowings

$ 160

$ 119,000

Borrowings, maturity

June 2,023

Corporate credit facilities | LIBOR | 166 MW wind portfolio | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

1.85%

1.85%

Corporate credit facilities | LIBOR | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

2.50%

2.50%

Corporate credit facilities | LIBOR | 377 MW hydroelectric portfolio | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

3.00%

Corporate credit facilities | CDI | Brazilian hydroelectric business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

2.00%

113.00%

113.00%

113.00%

2.00%

Corporate credit facilities | IBR | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

3.50%

3.50%

Corporate credit facilities | IBR | Colombian business | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, maturity

January 2,023

2,030

Borrowings, interest rate

0.70%

3.70%

0.70%

3.70%

Corporate credit facilities | CDOR | 488 MW hydroelectric portfolio | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

1.40%

1.40%

Corporate credit facilities | CDOR | 351 MW hydroelectric portfolio | Brookfield Renewable

Detailed Information About Borrowings

Borrowings, interest rate

1.60%

1.60%

BORROWINGS (Details - Supplemen

BORROWINGS (Details - Supplemental Information) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of credit facilities line item
Borrowings, Jan 1		$ 11,766	$ 10,182
Cash flows from financing activities	$ (1,080)	(27)	2,709
Borrowings, Dec 31	10,718		$ 11,766
Corporate Borrowings
Disclosure of credit facilities line item
Borrowings, Jan 1	2,393
Cash flows from financing activities	(88)
Non Cash Acquisitions	0
Non-cash Held For Sale	0
Other Borrowings	(130)
Borrowings, Dec 31	2,328	2,393
Non Recourse Borrowings
Disclosure of credit facilities line item
Borrowings, Jan 1	9,214
Cash flows from financing activities	(178)
Non Cash Acquisitions	90
Non-cash Held For Sale	(360)
Other Borrowings	(382)
Borrowings, Dec 31	$ 8,384	$ 9,214

NON-CONTROLLING INTERESTS (Deta

NON-CONTROLLING INTERESTS (Details - Summary) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	$ 8,129	$ 6,298	$ 5,589	$ 2,587
Non-controlling interests
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	12,015	9,815
Participating Non-controlling Interests Operating Subsidiaries
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	8,129	6,298
General partnership interest in a holding subsidiary held by Brookfield
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	66	58
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	3,252	2,843
Preferred equity
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	$ 568	$ 616

NON-CONTROLLING INTERESTS (De_2

NON-CONTROLLING INTERESTS (Details - Continuity) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of subsidiaries [line items]
Beginning Balance	$ 6,298	$ 5,589	$ 2,587
Net income	274	288	65
OCI	1,707	383	635
Capital contributions	(307)	(294)	(2,621)
Acquisition	21	525	1,417
Distributions			(119)
MTO adjustments		0	(1,616)
Purchase of Isagen shares		(1)
Other		(6)
Ending Balance	8,129	6,298	5,589
Brookfield Americas Infrastructure Fund
Disclosure of subsidiaries [line items]
Beginning Balance	850	963	958
Net income	1	(29)	(18)
OCI	66	(76)	46
Capital contributions	0	0	0
Acquisition	0	0	0
Distributions	(17)	(8)	(23)
MTO adjustments			0
Purchase of Isagen shares		0
Other	0	0
Ending Balance	$ 900	850	963
Brookfield Americas Infrastructure Fund | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	75.00%
Brookfield Americas Infrastructure Fund | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	80.00%
Brookfield Infrastructure Fund II
Disclosure of subsidiaries [line items]
Beginning Balance	$ 1,682	1,654	1,441
Net income	9	(13)	(16)
OCI	298	269	228
Capital contributions	9	89	74
Acquisition	0	0	0
Distributions	(81)	(317)	(73)
MTO adjustments			0
Purchase of Isagen shares		0
Other	12	0
Ending Balance	$ 1,929	1,682	1,654
Brookfield Infrastructure Fund II | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	43.00%
Brookfield Infrastructure Fund II | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	60.00%
Brookfield Infrastructure Fund III
Disclosure of subsidiaries [line items]
Beginning Balance	$ 1,852	1,085	0
Net income	86	33	15
OCI	805	111	0
Capital contributions	5	186	1,074
Acquisition	0	525	0
Distributions	(276)	(88)	(7)
MTO adjustments			3
Purchase of Isagen shares		(1)
Other	(3)	1
Ending Balance	$ 2,469	1,852	1,085
Interests held by third parties	25.00%
Brookfield Infrastructure Fund III | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	23.00%
Brookfield Infrastructure Fund III | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	71.00%
Canadian Hydroelectric Portfolio
Disclosure of subsidiaries [line items]
Beginning Balance	$ 0	0	0
Net income	4	0	0
OCI	(11)	0	0
Capital contributions	293	0	0
Acquisition	0	0	0
Distributions	0	0	0
MTO adjustments			0
Purchase of Isagen shares		0
Other	(10)	0
Ending Balance	$ 276	0	0
Interests held by third parties	25.00%
The Cataylst Group
Disclosure of subsidiaries [line items]
Beginning Balance	$ 134	127	121
Net income	14	12	16
OCI	(18)	2	2
Capital contributions	0	0	0
Acquisition	0	0	0
Distributions	(6)	(7)	(12)
MTO adjustments			0
Purchase of Isagen shares		0
Other	0	0
Ending Balance	$ 124	134	127
Interests held by third parties	53.00%
Isagen Institutional Investors
Disclosure of subsidiaries [line items]
Beginning Balance	$ 1,701	1,675	0
Net income	174	47	47
OCI	504	78	148
Capital contributions	0	19	1,473
Acquisition	0	0	0
Distributions	(167)	(115)	0
MTO adjustments			7
Purchase of Isagen shares		(5)
Other	0	2
Ending Balance	$ 2,212	1,701	1,675
Interests held by third parties	0.50%
Isagen Public non-controlling interests
Disclosure of subsidiaries [line items]
Beginning Balance	$ 9	14	0
Net income	1	0	19
OCI	5	(1)	205
Capital contributions	0	0	0
Acquisition	0	0	1,417
Distributions	0	0	0
MTO adjustments			(1,627)
Purchase of Isagen shares		5
Other	0	(9)
Ending Balance	15	9	14
Other
Disclosure of subsidiaries [line items]
Beginning Balance	70	71	67
Net income	8	3	2
OCI	58	0	6
Capital contributions	0	0	0
Acquisition	21	0	0
Distributions	(6)	(4)	(4)
MTO adjustments			0
Purchase of Isagen shares		0
Other	53	0
Ending Balance	$ 204	70	71
Other | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	20.00%
Other | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	50.00%
Subsidiaries with material non-controlling interests
Disclosure of subsidiaries [line items]
Beginning Balance	$ 8,129	6,298
Net income	297	53	65
OCI	1,707	383	635
Capital contributions	307	294	2,621
Acquisition	21	525	1,417
Distributions	(553)	(539)	(119)
MTO adjustments			(1,617)
Purchase of Isagen shares		(1)
Other	52	(6)
Ending Balance	$ 8,129	$ 8,129	$ 6,298

NON-CONTROLLING INTERESTS (De_3

NON-CONTROLLING INTERESTS (Details - Summary information) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of subsidiaries [line items]
Revenues	$ 2,982	$ 2,625	$ 2,452
Net (loss) income	403	51	40
Comprehensive income	3,667	1,401	1,369
Profit Loss Attributable To Noncontrolling Interests	274	288	65
Property, plant and equipment, at fair value	29,025	27,096	25,257	$ 18,358
Total assets	34,103	30,904
Total liabilities	16,897	16,622
Total borrowings	10,718		11,766	10,182
Carrying value of non-controlling interests	$ 8,129	6,298	5,589	2,587
Brookfield Americas Infrastructure Fund
Disclosure of subsidiaries [line items]
Place of business	United States, Brazil
Revenues	$ 157	123	118
Net (loss) income	2	(34)	(22)
Comprehensive income	95	(133)	37
Profit Loss Attributable To Noncontrolling Interests	1	(29)	(18)
Property, plant and equipment, at fair value	1,687	1,667
Total assets	1,737	1,718
Total liabilities	536	556
Total borrowings	582	628
Carrying value of non-controlling interests	$ 900	850	963	958
Brookfield Americas Infrastructure Fund | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	75.00%
Brookfield Americas Infrastructure Fund | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	80.00%
Brookfield Infrastructure Fund II
Disclosure of subsidiaries [line items]
Place of business	United States, Brazil, Europe
Revenues	$ 447	430	394
Net (loss) income	17	(20)	(23)
Comprehensive income	544	529	356
Profit Loss Attributable To Noncontrolling Interests	9	(13)	(16)
Property, plant and equipment, at fair value	5,553	5,153
Total assets	5,831	5,430
Total liabilities	1,979	2,040
Total borrowings	2,395	2,422
Carrying value of non-controlling interests	$ 1,929	1,682	1,654	1,441
Brookfield Infrastructure Fund II | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	43.00%
Brookfield Infrastructure Fund II | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	60.00%
Brookfield Infrastructure Fund III
Disclosure of subsidiaries [line items]
Interests held by third parties	25.00%
Place of business	United States, Brazil, India, China
Revenues	$ 311	53	28
Net (loss) income	19	18	(8)
Comprehensive income	898	126	(8)
Profit Loss Attributable To Noncontrolling Interests	86	33	15
Property, plant and equipment, at fair value	2,322	2,149
Total assets	3,725	3,294
Total liabilities	838	1,502
Total borrowings	1,441	1,678
Carrying value of non-controlling interests	$ 2,469	1,852	1,085	0
Brookfield Infrastructure Fund III | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	23.00%
Brookfield Infrastructure Fund III | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	71.00%
Canadian Hydroelectric Portfolio
Disclosure of subsidiaries [line items]
Interests held by third parties	25.00%
Place of business	Canada
Revenues	$ 38	0	0
Net (loss) income	15	0	0
Comprehensive income	25	0	0
Profit Loss Attributable To Noncontrolling Interests	4	0	0
Property, plant and equipment, at fair value	1,679	0
Total assets	1,975	0
Total liabilities	924	0
Total borrowings	1,933	0
Carrying value of non-controlling interests	$ 276	0	0	0
The Cataylst Group
Disclosure of subsidiaries [line items]
Interests held by third parties	53.00%
Place of business	United States
Revenues	$ 142	135	164
Net (loss) income	56	47	62
Comprehensive income	(16)	57	70
Profit Loss Attributable To Noncontrolling Interests	14	12	16
Property, plant and equipment, at fair value	875	964
Total assets	982	1,066
Total liabilities	369	413
Total borrowings	387	432
Carrying value of non-controlling interests	$ 124	134	127	121
Isagen
Disclosure of subsidiaries [line items]
Interests held by third parties	76.00%
Place of business	Colombia
Revenues	$ 896	797	819
Net (loss) income	331	89	110
Comprehensive income	1,290	236	502
Profit Loss Attributable To Noncontrolling Interests	251	67	86
Property, plant and equipment, at fair value	6,665	5,401
Total assets	7,717	6,526
Total liabilities	1,744	1,858
Total borrowings	3,548	3,336
Carrying value of non-controlling interests	$ 3,169	2,424
Other
Disclosure of subsidiaries [line items]
Interests held by third parties	50.00%
Place of business	United States, Brazil, Canada
Revenues	$ 21	32	27
Net (loss) income	2	7	5
Comprehensive income	16	0	31
Profit Loss Attributable To Noncontrolling Interests	1	3	2
Property, plant and equipment, at fair value	253	411
Total assets	293	426
Total liabilities	70	42
Total borrowings	88	63
Carrying value of non-controlling interests	$ 52	70
Isagen Institutional Investors
Disclosure of subsidiaries [line items]
Interests held by third parties	0.50%
Profit Loss Attributable To Noncontrolling Interests	$ 174	47	47
Carrying value of non-controlling interests	2,212	1,701	1,675	0
Isagen Public non-controlling interests
Disclosure of subsidiaries [line items]
Profit Loss Attributable To Noncontrolling Interests	1	0	19
Carrying value of non-controlling interests	15	9	14	$ 0
Subsidiaries with material non-controlling interests
Disclosure of subsidiaries [line items]
Revenues	2,012	1,570	1,550
Net (loss) income	442	107	124
Comprehensive income	2,852	815	988
Profit Loss Attributable To Noncontrolling Interests	297	53	65
Property, plant and equipment, at fair value	19,034	15,745
Total assets	22,260	18,460
Total liabilities	6,460	6,411
Total borrowings	10,374	8,559
Carrying value of non-controlling interests	$ 8,129	$ 8,129	$ 6,298

NON-CONTROLLING INTERESTS (De_4

NON-CONTROLLING INTERESTS (Details - GP REU distributions and summary) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Non-controlling interests [member]
Disclosure of dividends [line items]
Distributions, Dollar	$ 300	$ 278
Disclosure of summary financial information [line items]
Revenues	2,982	2,625	$ 2,452
Net (loss) income	403	51	40
Comprehensive income	3,667	1,401	$ 1,369
Net (loss) income attributable to:
Property, plant and equipment, at fair value	29,025	27,096
Total assets	34,103	30,904
Total borrowings	10,718	11,766
Total liabilities	16,897	16,622
Carrying value of:
Non controlling Interests	$ 12,015	$ 9,815
Non-controlling interests [member] | BRELP
Disclosure of dividends [line items]
Distributions, per share	$ 0.4225
Incentive Distribution, Percent	25.00%
Non-controlling interests [member] | LP Units
Carrying value of:
Common units outstanding	180,200,000	173,500,000	156,400,000
Weighted average number of units	178,800,000	180,400,000
Non-controlling interests [member] | LP Units | BRELP
Disclosure of dividends [line items]
Distributions, per share	$ 0.375
Incentive Distribution, Percent	15.00%
Non-controlling interests [member] | GP interests
Disclosure of dividends [line items]
Distributions, Dollar	$ 45	$ 35
Net (loss) income attributable to:
Non-controlling interests	1	(1)	$ 0
Carrying value of:
Non controlling Interests	$ 66	$ 58
Common units outstanding	2,651,506	2,651,506	2,700,000
Weighted average number of units	2,700,000	2,700,000
Non-controlling interests [member] | Redeemable/Exchangeable partnership units
Net (loss) income attributable to:
Non-controlling interests	$ 17	$ (23)	$ (29)
Carrying value of:
Non controlling Interests	$ 3,252	$ 2,843
Common units outstanding	129,658,623	129,658,623	129,700,000
Weighted average number of units	129,700,000	129,700,000
General partnership interest in a holding subsidiary held by Brookfield
Disclosure of summary financial information [line items]
Net (loss) income	$ 1	$ (1)	$ 0
Net (loss) income attributable to:
Non-controlling interests	1	(1)	0
Carrying value of:
Non controlling Interests	$ 66	58
General partnership interest in a holding subsidiary held by Brookfield | BRELP
Disclosure of dividends [line items]
Owership percentage	1.00%
General partnership interest in a holding subsidiary held by Brookfield | GP interests
Disclosure of dividends [line items]
Distributions, Dollar	$ 5	5
Incentive Distribution | GP interests
Disclosure of dividends [line items]
Distributions, Dollar	40	30
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of summary financial information [line items]
Net (loss) income	17	(23)	(29)
Net (loss) income attributable to:
Non-controlling interests	17	(23)	$ (29)
Carrying value of:
Non controlling Interests	3,252	2,843
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield | Redeemable/Exchangeable partnership units
Disclosure of dividends [line items]
Distributions, Dollar	$ 255	$ 243

NON-CONTROLLING INTERESTS (De_5

NON-CONTROLLING INTERESTS (Details - Preferred Equity) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of preference shares [Line Items]
Dividends declared for the year ended	$ (1,272)	$ (1,199)	$ (696)
Non controlling Interests	$ 8,129	6,298	$ 5,589	$ 2,587
Preferred equity
Disclosure of preference shares [Line Items]
Shares outstanding	31,030
Dividends declared for the year ended	$ 26	26
Non controlling Interests	$ 568	616
Series 1 (C$136)
Disclosure of preference shares [Line Items]
Cumulative dividend rate (%)	3.36%
Earliest permitted redemption date	Apr 2,020
Dividends declared for the year ended	$ 4	4
Non controlling Interests		108
Series 2 (C$113)
Disclosure of preference shares [Line Items]
Cumulative dividend rate (%)	4.29%
Earliest permitted redemption date	Apr 2,020
Dividends declared for the year ended	$ 3	3
Non controlling Interests		90
Series 3 (C$249)
Disclosure of preference shares [Line Items]
Cumulative dividend rate (%)	4.40%
Earliest permitted redemption date	Jul 2,019
Dividends declared for the year ended	$ 8	8
Non controlling Interests		197
Series 5 (C$103)
Disclosure of preference shares [Line Items]
Cumulative dividend rate (%)	5.00%
Earliest permitted redemption date	Apr 2,018
Dividends declared for the year ended	$ 4	4
Non controlling Interests		82
Series 6 (C$175)
Disclosure of preference shares [Line Items]
Cumulative dividend rate (%)	5.00%
Earliest permitted redemption date	Jul 2,018
Dividends declared for the year ended	$ 7	7
Non controlling Interests		$ 139
Class A Preference Shares
Disclosure of preference shares [Line Items]
Percentage of units for normal course issuer bid	10.00%

PREFERRED LIMITED PARTNERS EQ_3

PREFERRED LIMITED PARTNERS EQUITY (Details) $ / shares in Units, $ in Millions, $ in Millions	Jan. 16, 2018CAD ($)$ / sharesshares	Jan. 16, 2018USD ($)	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)
Disclosure of preferred limited partners [Line Items]
Dividends declared for the year ended			$ 38
Preferred limited partners' equity			$ 707	$ 511
Preferred Limited Partners Unit [Member]
Disclosure of preferred limited partners [Line Items]
Number of shares outstanding | shares			37,890,000
Dividends declared for the year ended				28
Preferred limited partners' equity			$ 707
Series 5 (C$72)
Disclosure of preferred limited partners [Line Items]
Number of shares outstanding | shares			2,890,000
Dividend rate			5.59%
Earliest redemption date			Apr 2,018
Dividends declared for the year ended			$ 4	4
Preferred limited partners' equity			$ 49	49
Series 7 (C$175)
Disclosure of preferred limited partners [Line Items]
Number of shares outstanding | shares			7,000,000
Dividend rate			5.50%
Earliest redemption date			Jan 2,021
Dividends declared for the year ended			$ 7	8
Preferred limited partners' equity			$ 128	128
Series 9 (C$200)
Disclosure of preferred limited partners [Line Items]
Number of shares outstanding | shares			8,000,000
Dividend rate			5.75%
Earliest redemption date			Jul 2,021
Dividends declared for the year ended			$ 9	8
Preferred limited partners' equity			$ 147	147
Series 11 (C$250)
Disclosure of preferred limited partners [Line Items]
Number of shares outstanding | shares			10,000,000
Dividend rate			5.00%
Earliest redemption date			Apr 2,022
Dividends declared for the year ended			$ 9	8
Preferred limited partners' equity			$ 187	187
Series 13 (C$250)
Disclosure of preferred limited partners [Line Items]
Number of shares outstanding | shares			10,000,000
Dividend rate	5.00%	5.00%	5.00%
Earliest redemption date			Apr 2,023
Dividends declared for the year ended			$ 9	0
Preferred limited partners' equity			$ 196	$ 0
Proceeds from issuing shares	$ 250	$ 201
Share issue related cost	$ 7	$ 5
Par Value Per Share | $ / shares	$ 25
Number of shares issued | shares	10,000,000
Series 13 (C$250) | Government of Canada Bond yield plus
Disclosure of preferred limited partners [Line Items]
Dividend rate	3.00%	3.00%
Dividend rate reset period	April 30, 2023	April 30, 2023
Class A Preference Shares
Disclosure of preferred limited partners [Line Items]
Percentage of units for normal course issuer bid			10.00%

LIMITED PARTNERS EQUITY (Detail

LIMITED PARTNERS EQUITY (Details) - USD ($)	1 Months Ended		12 Months Ended
	Feb. 28, 2019	Dec. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of limited partners equity [Line Items]
Dividends recognised as distributions to owners			$ 38,000,000
Preferred limited partner units and limited partner units adjusted				$ 0	$ 0
Brookfield Asset Management
Disclosure of limited partners equity [Line Items]
Number of shares outstanding		185,727,567	185,727,567
Ownership percentage		60.00%	60.00%
Brookfield Asset Management | Direct ownership | Ownership interest in BEP
Disclosure of limited partners equity [Line Items]
Ownership percentage		31.00%	31.00%
Brookfield Asset Management | Direct ownership | Ownership interest in BRELP
Disclosure of limited partners equity [Line Items]
Ownership percentage		42.00%	42.00%
Public shareholders
Disclosure of limited partners equity [Line Items]
Ownership percentage		40.00%	40.00%
LP Units
Disclosure of limited partners equity [Line Items]
Number of shares outstanding		178,821,204	178,821,204
Dividends recognised as distributions to owners	$ 2.06		$ 355,000,000	328,000,000
Dividends paid, ordinary shares per share	$ 0.1
Maximum units for normal course issuer bid		8,900,000	8,900,000
Percentage of units for normal course issuer bid		5.00%	5.00%
Number of shares repurchased	1,856,798	20,000,000,000
Cost of Units repurchased on the Toronto Stock Exchange and the New York Stock Exchange	$ 51,000,000
LP Units | Distribution reinvestment plan
Disclosure of limited partners equity [Line Items]
Share issue related cost			$ 8,000,000	$ 10,000,000
Number of shares issued		289,641	289,641	302,037
LP Units | Brookfield Asset Management
Disclosure of limited partners equity [Line Items]
Number of shares outstanding		56,068,944	56,068,944	56,068,944
Dividends recognised as distributions to owners			$ 110,000,000	$ 101,000,000
LP Units | Public shareholders
Disclosure of limited partners equity [Line Items]
Dividends recognised as distributions to owners			$ 245,000,000	$ 227,000,000
GP interests | Brookfield Asset Management | Ownership interest in BEP
Disclosure of limited partners equity [Line Items]
Ownership percentage		0.01%	0.01%
GP interests | Brookfield Asset Management | Ownership interest in BRELP
Disclosure of limited partners equity [Line Items]
Ownership percentage		1.00%	1.00%

GOODWILL (Details)

GOODWILL (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)
Changes in goodwill [abstract]
Beginning of year	$ 901
Acquired through business acquisition	27
Transfer to Assets held for sale	(22)
Foreign exchange	(78)
End of year	828
Deferred tax liability (asset)	$ 27

CAPITAL MANAGEMENT (Details)

CAPITAL MANAGEMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of objectives, policies and processes for managing capital [line items]
Corporate Borrowings	$ 6	$ 159
Non Recourse Borrowings	7,895	7,697
Total borrowings	10,718		$ 11,766	$ 10,182
Deferred income tax liabilities, net		4,049	3,411
Equity	17,206	14,282	12,672	8,763
Non-controlling interests
Disclosure of objectives, policies and processes for managing capital [line items]
Total borrowings	10,718	11,766
Preferred limited partners' equity
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	$ 707	$ 511	$ 324	$ 128
Top of range
Disclosure of objectives, policies and processes for managing capital [line items]
Debt to total capitalization ratio	34.00%	40.00%
Bottom of range
Disclosure of objectives, policies and processes for managing capital [line items]
Debt to total capitalization ratio	20.00%	24.00%
Terraform Global
Disclosure of objectives, policies and processes for managing capital [line items]
Corporate Borrowings	$ 13
Total borrowings	$ 183
Terraform Global | Top of range
Disclosure of objectives, policies and processes for managing capital [line items]
Borrowings, maturity	2,026
Terraform Global | Bottom of range
Disclosure of objectives, policies and processes for managing capital [line items]
Borrowings, maturity	2,031
Corporate
Disclosure of objectives, policies and processes for managing capital [line items]
Corporate Borrowings	$ 2,334	$ 2,552
Non Recourse Borrowings	0	0
Total borrowings	2,334	2,552
Deferred income tax liabilities, net	0	0
Capitalization, net	$ 11,411	$ 10,536
Debt to total capitalization	20.00%	24.00%
Corporate | Non-controlling interests
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	$ 0	$ 0
Corporate | Preferred Equity
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	568	616
Corporate | Preferred limited partners' equity
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	707	511
Corporate | Unitholders Equity
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	7,802	6,857
Consolidated
Disclosure of objectives, policies and processes for managing capital [line items]
Corporate Borrowings	2,334	2,552
Non Recourse Borrowings	8,384	9,214
Total borrowings	10,718	11,766
Deferred income tax liabilities, net	4,049	3,411
Capitalization, net	$ 31,973	$ 29,459
Debt to total capitalization	34.00%	40.00%
Consolidated | Non-controlling interests
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	$ 8,129	$ 6,298
Consolidated | Preferred Equity
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	568	616
Consolidated | Preferred limited partners' equity
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	707	511
Consolidated | Unitholders Equity
Disclosure of objectives, policies and processes for managing capital [line items]
Equity	$ 7,802	$ 6,857

EQUITY-ACCOUNTED INVESTMENTS (D

EQUITY-ACCOUNTED INVESTMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 31, 2016
Disclosure of joint ventures [line items]
Carrying value	$ 1,569	$ 721	$ 197	$ 206
Balance, beginning of year	721		197
Investment	420	469	0
Share of net income	(68)	(2)	0
Share of net comprehensive income	426	56	8
Dividends declared	(42)	(31)	(6)
Foreign exchange translation and other	(42)	(31)	$ (6)
Balance, end of year	$ 1,569	$ 721

EQUITY-ACCOUNTED INVESTMENTS _2

EQUITY-ACCOUNTED INVESTMENTS (Details - Summary Information) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of joint ventures [line items]
Revenue	$ 1,305	$ 310	$ 74
Net (loss) income	223	(24)	0
Share of net income (loss): Cash Earnings	130	29	9
Share of net income (loss): Non-cash loss	(62)	(27)	$ (9)
Current assets	682	477
Property, plant and equipment, at fair value	11,999	8,098
Other assets	608	213
Current liabilities	1,080	687
Non-recourse Borrowings	6,078	4,294
Other liabilities	$ 1,197	$ 822

CASH AND CASH EQUIVALENTS (Deta

CASH AND CASH EQUIVALENTS (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash And Cash Equivalents [Line Items]
Cash	$ 127	$ 790
Short-term deposit	46	9
Cash and cash equivalents, net	$ 173	$ 799	$ 223	$ 63

RESTRICTED CASH (Details)

RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure Restricted Cash [Abstract]
Operations	$ 119	$ 195
Credit obligations	60	85
Development projects	2	4
Restricted Cash And Cash Equivalents, net	181	284	$ 284
Less: non-current	(45)	(103)
Current	$ 136	$ 181

TRADE RECEIVABLES AND OTHER C_3

TRADE RECEIVABLES AND OTHER CURRENT ASSETS (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Disclosure Trade Receivables and Other Current Assets [Abstract]
Trade receivables	$ 339	$ 360
Other short-term receivables	114	112
Prepaids and others	109	82
Trade receivables and other current assets, net	$ 607	$ 554
% of trade AR that is current	74.00%	99.00%

OTHER LONG-TERM ASSETS (Details

OTHER LONG-TERM ASSETS (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Other Long term assets [Line Items]
Contract Assets	$ 402,000,000	$ 0
Restricted cash	(45,000,000)	(103,000,000)
Other	58,000,000	81,000,000
Other long-term assets, net	$ 505,000,000	$ 230,000,000

ACCOUNTS PAYABLE AND ACCRUED _3

ACCOUNTS PAYABLE AND ACCRUED LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Disclosure Accounts Payable and Accured Liabilities [Abstract]
Operating accrued liabilities	$ 263	$ 271
Accounts payable	76	117
Current interest payable	76	64
Deferred consideration	30	35
LP unitholders' distributions, preferred limited partnership unit distributions and preferred dividends payable	30	29
Other	58	26
Total accounts payable and accrued liabilities	$ 533	$ 542

OTHER LONG-TERM LIABILITIES (De

OTHER LONG-TERM LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Disclosure Other Long Term Liabilities [Line Items]
Deferred Revenue	$ 479	$ 9
Pension obligations	80	89
Acquisition related provisions	69	80
Decommissioning retirement obligations	67	85
Concession payment liability	7	9
Commitments for power purchase agreement	6	13
Contingent considerations	3	18
Other	23	41
Other long-term liabilities, net	$ 734	$ 344

COMMITMENTS, CONTINGENCIES AN_3

COMMITMENTS, CONTINGENCIES AND GUARANTEES (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Disclosure of finance lease and operating lease by lessee [line items]
Various agreements can be renewed and are extendable, maximum year	2,091
Minimum lease payments	$ 250,000,000
Development Project Cost	71,000,000	$ 44,000,000
Estimated contingent liabilities for letters of credit	389,000,000	544,000,000
Brookfield Renewable along with institutional investors
Disclosure of finance lease and operating lease by lessee [line items]
Estimated contingent liabilities for letters of credit	51,000,000	76,000,000
Brookfield Renewable's subsidiaries
Disclosure of finance lease and operating lease by lessee [line items]
Estimated contingent liabilities for letters of credit	338,000,000	$ 468,000,000
2,019
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	31,000,000
Development Project Cost	46,000,000
2,020
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	29,000,000
Development Project Cost	25,000,000
2,021
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	25,000,000
2,022
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	22,000,000
2,023
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	18,000,000
Thereafter
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	$ 125,000,000

RELATED PARTY (Details - PPA)

RELATED PARTY (Details - PPA) $ in Millions	12 Months Ended
	Dec. 31, 2018USD ($)$ / MWh$ / MWhGWh	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Disclosure of transactions between related parties [line items]
Management Fee Expense | $	$ 80	$ 82	$ 62
Energy marketing fees | $	$ 24	24	23
Power purchase agreement BPUSHA
Disclosure of transactions between related parties [line items]
Reduction in price per MWh	5.03
Initial expiry date	2,026
Brookfield Renewable
Disclosure of transactions between related parties [line items]
Management Fee Expense | $	$ 80	$ 82	$ 62
Management fee fixed component | $	21
Management fee fixed component quarterly | $	5
Capitalization for management fees | $	16,000
Initial capitalization for management fees | $	8
Energy marketing fees | $	$ 18
Brookfield Renewable | Power purchase agreement GLPL
Disclosure of transactions between related parties [line items]
Average price per MWh	100
Average Price Adjustment Fixed Rate Percent	3.00%
Option to extend a fixed price commitment, per MWh	60
Initial expiry date	2,029
Option to extend a fixed price commitment, Year	2,044
Brookfield Renewable | Power purchase agreement MPT
Disclosure of transactions between related parties [line items]
Average price per MWh	127
Average Price Adjustment Fixed Rate Percent	3.00%
Initial expiry date	2,029
Brookfield Renewable | Power purchase agreement BPUSHA
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI	40.00%
Reduction in price per MWh	3
Contact Termination date	2,046
Maximum annual increment in power purchase agreements	3.00%
Eletricity prices	75
Brookfield Renewable | Power purchase agreement BPUSHA | Top of range
Disclosure of transactions between related parties [line items]
Option to extend a fixed price commitment, Year	2,021
Brookfield Renewable | Power purchase agreement BPUSHA | Bottom of range
Disclosure of transactions between related parties [line items]
Option to extend a fixed price commitment, Year	2,025
Brookfield Renewable | Power purchase agreement GLHA
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI	20.00%
Eletricity prices	37
Brookfield Renewable | Power purchase agreement Lievre power
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI	40.00%
Maximum annual increment in power purchase agreements	3.00%
Eletricity prices	68
Brookfield Renewable | Power purchase agreement hydro pontiac one
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI	40.00%
Initial expiry date	2,029
Commencement date of power purchase agreements	2,019
Eletricity prices	68
Brookfield Renewable | Power purchase agreement hydro pontiac two
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI	40.00%
Commencement date of power purchase agreements	2,020
Eletricity prices	68
Brookfield Renewable | Power purchase agreement wind levelization
Disclosure of transactions between related parties [line items]
Initial expiry date	2,019
Expected generation | GWh	506

RELATED PARTY (Details - Voting

RELATED PARTY (Details - Voting agreements) - Brookfield Renewable	12 Months Ended
	Dec. 31, 2018
Subsidiaries with material non-controlling interests [member]
Disclosure of transactions between related parties [line items]
Proportion of ownership interest in subsidiary	30.00%
Bottom of range | Brookfield Americas Infrastructure Fund
Disclosure of transactions between related parties [line items]
Proportion of ownership interest in subsidiary	22.00%
Bottom of range | Brookfield Infrastructure Fund II
Disclosure of transactions between related parties [line items]
Proportion of ownership interest in subsidiary	40.00%
Bottom of range | Brookfield Infrastructure Fund III
Disclosure of transactions between related parties [line items]
Proportion of ownership interest in subsidiary	24.00%
Top of range | Brookfield Americas Infrastructure Fund
Disclosure of transactions between related parties [line items]
Proportion of ownership interest in subsidiary	25.00%
Top of range | Brookfield Infrastructure Fund II
Disclosure of transactions between related parties [line items]
Proportion of ownership interest in subsidiary	50.10%
Top of range | Brookfield Infrastructure Fund III
Disclosure of transactions between related parties [line items]
Proportion of ownership interest in subsidiary	31.00%

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details - Income Statement) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenues
Power purchase and revenue agreements	$ 535	$ 601	$ 527
Wind levelization agreement	7	6	8
Total related party revenues	542	607	535
Direct operating costs
Energy purchases	(20)	(13)	(3)
Energy marketing fee	(24)	(24)	(23)
Insurace services	(25)	(19)	(20)
Total related party direct operating costs	(69)	(56)	(46)
Interest (expense) income - borrowings	(8)	0	6
Management service costs	$ 80	$ 82	$ 62

RELATED PARTY TRANSACTIONS (D_2

RELATED PARTY TRANSACTIONS (Details - Balance Sheet) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017
Disclosure of transactions between related parties [line items]
Due from related parties	$ 65	$ 60
Due to related parties	101	112
Brookfield Renewable
Disclosure of transactions between related parties [line items]
Due from related parties	55	54
Due to related parties	54	48
Accrued distributions payable on LP Units and Redeemable/Exchangeable partnership units	35	32
Equity-accounted investments and other
Disclosure of transactions between related parties [line items]
Due from related parties	10	6
Due to related parties	$ 12	$ 32

SUPPLEMENTAL INFORMATION (Detai

SUPPLEMENTAL INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Supplemental cash flow information:
Trade receivables and other current assets	$ (122)	$ (40)	$ 30
Accounts payable and accrued liabilities	32	32	(160)
Other assets and liabilities	22	(17)	(7)
Net change in working capital balances	$ 68	$ 25	$ 137

PENSION AND EMPLOYEE FUTURE B_3

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Actuarial Assumptions)	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined benefit pension plans | Bottom of range
Disclosure of actuarial assumptions [line items]
Actuarial assumption of discount rates	2.50%	2.40%	2.20%
Actuarial assumption of expected rates of inflation	1.50%	1.50%	1.50%
Actuarial assumption of expected rates of salary increases	2.50%	2.50%	2.50%
Defined benefit pension plans | Top of range
Disclosure of actuarial assumptions [line items]
Actuarial assumption of discount rates	7.20%	7.30%	7.30%
Actuarial assumption of expected rates of inflation	3.50%	3.50%	3.50%
Actuarial assumption of expected rates of salary increases	4.00%	4.00%	4.00%
Non-pension benefit plans | Bottom of range
Disclosure of actuarial assumptions [line items]
Actuarial assumption of discount rates	3.90%	3.70%	4.10%
Actuarial assumption of expected rates of salary increases	2.50%	2.50%	2.50%
Actuarial assumption of medical cost trend rates	5.30%	5.30%	5.30%
Non-pension benefit plans | Top of range
Disclosure of actuarial assumptions [line items]
Actuarial assumption of discount rates	7.40%	7.10%	7.30%
Actuarial assumption of expected rates of salary increases	4.00%	4.00%	4.00%
Actuarial assumption of medical cost trend rates	6.90%	6.90%	6.90%

PENSION AND EMPLOYEE FUTURE B_4

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Sensitivity Analysis) $ in Millions	Dec. 31, 2018USD ($)
Actuarial assumption of discount rates | Defined benefit pension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
50 basis point increase	$ (7)
50 basis point decrease	8
Actuarial assumption of discount rates | Non-pension benefit plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
50 basis point increase	(4)
50 basis point decrease	4
Actuarial assumption of expected rates of inflation | Defined benefit pension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
50 basis point increase	4
50 basis point decrease	(4)
Actuarial assumption of medical cost trend rates | Non-pension benefit plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
50 basis point increase	3
50 basis point decrease	$ (3)

PENSION AND EMPLOYEE FUTURE B_5

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Expenses) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined benefit pension plans
Disclosure Of Defined Benefit Plans Expense [Line Items]
Current service cost	$ 3	$ 3	$ 3
Past service cost (recovery)	0	(1)	0
Interest expense	2	2	2
Administrative expense	1	1	1
Recognized in consolidated statement of income	6	5	6
Remeasurement losses (gains)
Return on plan assets	5	(8)	(2)
Actuarial changes arising from changes in demographic assumptions	(1)	1	(1)
Actuarial changes arising from changes in financial assumptions	(9)	7	5
Experience adjustments	1	0	0
Recognized in consolidated statement of comprehensive income	(4)	0	2
Defined benefit expense gain loss recognized, net	2	5	8
Non-pension benefit plans
Disclosure Of Defined Benefit Plans Expense [Line Items]
Current service cost	2	1	1
Past service cost (recovery)	0	0	0
Interest expense	3	3	3
Administrative expense	0	0	0
Recognized in consolidated statement of income	5	4	4
Remeasurement losses (gains)
Return on plan assets	0	0	0
Actuarial changes arising from changes in demographic assumptions	0	(2)	(1)
Actuarial changes arising from changes in financial assumptions	(4)	3	1
Experience adjustments	(1)	1	0
Recognized in consolidated statement of comprehensive income	(5)	2	0
Defined benefit expense gain loss recognized, net	$ 0	$ 6	$ 4

PENSION AND EMPLOYEE FUTURE B_6

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Net position) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined benefit pension plans
Disclosure of net defined benefit liability (asset) [line items]
Present value of defined benefit obligation	$ 157	$ 172	$ 158	$ 124
Plan assets, at fair value	(126)	(135)	(119)
Net defined benefit liability (asset)	31	37	39
Non-pension benefit plans
Disclosure of net defined benefit liability (asset) [line items]
Present value of defined benefit obligation	53	57	53	$ 35
Plan assets, at fair value	(4)	(5)	(5)
Net defined benefit liability (asset)	$ 49	$ 52	$ 48

PENSION AND EMPLOYEE FUTURE B_7

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Defined benefit obligations) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined benefit pension plans
Disclosure of net defined benefit liability (asset) [line items]
Balance, beginning of year	$ 157	$ 172	$ 158	$ 124
Current service cost		3	3	3
Past service cost (recovery)		0	(1)	0
Interest expense		7	7	7
Remeasurement losses (gains)
Actuarial changes arising from changes in demographic assumptions		(1)	1	(1)
Actuarial changes arising from changes in financial assumptions		(9)	7	5
Experience adjustments		1	0	0
Benefits paid		(9)	(7)	(8)
Business combination		0	0	25
Exchange differences		(7)	4	3
Balance, end of year		157	172	158
Employer contribution	10
Non-pension benefit plans
Disclosure of net defined benefit liability (asset) [line items]
Balance, beginning of year	$ 53	57	53	35
Current service cost		2	1	1
Past service cost (recovery)		0	0	0
Interest expense		3	3	3
Remeasurement losses (gains)
Actuarial changes arising from changes in demographic assumptions		0	(2)	(1)
Actuarial changes arising from changes in financial assumptions		(4)	3	1
Experience adjustments		(1)	1	0
Benefits paid		(2)	(2)	(2)
Business combination		0	0	14
Exchange differences		(2)	0	2
Balance, end of year		$ 53	$ 57	$ 53

PENSION AND EMPLOYEE FUTURE B_8

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Plan assets) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Defined benefit pension plans
Disclosure of plan assets [line items]
Balance, beginning of year	$ (126)	$ (135)	$ (119)
Return on plan assets		5	(8)	$ (2)
Employer contribution	10
Business combination		0	0	25
Benefits paid		(9)	(7)	(8)
Exchange differences		(7)	4	3
Balance, end of year		(126)	(135)	(119)
Defined benefit pension plans | Plan assets
Disclosure of plan assets [line items]
Balance, beginning of year	126	135	119	103
Interest income		5	5	5
Return on plan assets		(5)	8	2
Employer contribution		5	5	7
Business combination		0	0	9
Benefits paid		(9)	(7)	(8)
Exchange differences		(5)	5	1
Balance, end of year		126	135	119
Non-pension benefit plans
Disclosure of plan assets [line items]
Balance, beginning of year	(4)	(5)	(5)
Return on plan assets		0	0	0
Business combination		0	0	14
Benefits paid		(2)	(2)	(2)
Exchange differences		(2)	0	2
Balance, end of year		(4)	(5)	(5)
Non-pension benefit plans | Plan assets
Disclosure of plan assets [line items]
Balance, beginning of year	$ 4	5	5	0
Interest income		0	0	0
Return on plan assets		(1)	0	0
Employer contribution		2	2	3
Business combination		0	0	4
Benefits paid		(2)	(2)	(2)
Exchange differences		0	0	0
Balance, end of year		$ 4	$ 5	$ 5

PENSION AND EMPLOYEE FUTURE B_9

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Category of assets)	Dec. 31, 2018	Dec. 31, 2017
Disclosure of fair value of plan assets [abstract]
Cash and cash equivalents	2.00%	2.00%
Equity securities	47.00%	54.00%
Debt securities	51.00%	44.00%
Real estate	0.00%	0.00%
Total	100.00%	100.00%

SUBSIDIARY PUBLIC ISSUERS (Deta

SUBSIDIARY PUBLIC ISSUERS (Details - Balance Sheet) - USD ($) $ in Millions	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of subsidiaries [line items]
Current assets	$ 1,961	$ 1,666
Long-term assets	32,142	29,238
Current liabilities	1,689	2,514
Long-term liabilities	15,208	14,108
Non controlling Interests	8,129	6,298	$ 5,589	$ 2,587
Equity	17,206	14,282	12,672	8,763
Non-controlling interests
Disclosure of subsidiaries [line items]
Non controlling Interests	12,015	9,815
Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Non controlling Interests	8,129	6,298
Equity	8,129	6,298	5,589	2,587
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	3,252	2,843
Equity	3,252	2,843	2,680	2,559
Preferred equity
Disclosure of subsidiaries [line items]
Non controlling Interests	568	616
Equity	568	616	576	610
Preferred Limited Partners equity
Disclosure of subsidiaries [line items]
Equity	707	511
General partnership interest in a holding subsidiary held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	66	58
Equity	66	58	$ 55	$ 52
Brookfield Renewable
Disclosure of subsidiaries [line items]
Current assets	32	32
Long-term assets	5,208	4,483
Current liabilities	38	43
Long-term liabilities	0	0
Brookfield Renewable | Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Brookfield Renewable | Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Brookfield Renewable | Preferred equity
Disclosure of subsidiaries [line items]
Equity	0	0
Brookfield Renewable | Preferred Limited Partners equity
Disclosure of subsidiaries [line items]
Equity	707	511
BRP Equity
Disclosure of subsidiaries [line items]
Current assets	389	412
Long-term assets	239	262
Current liabilities	6	7
Long-term liabilities	0	0
BRP Equity | Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
BRP Equity | Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
BRP Equity | Preferred equity
Disclosure of subsidiaries [line items]
Equity	568	616
BRP Equity | Preferred Limited Partners equity
Disclosure of subsidiaries [line items]
Equity	0	0
Finco
Disclosure of subsidiaries [line items]
Current assets	1,631	1,691
Long-term assets	1	0
Current liabilities	21	180
Long-term liabilities	1,607	1,505
Finco | Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Finco | Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Finco | Preferred equity
Disclosure of subsidiaries [line items]
Equity	0	0
Finco | Preferred Limited Partners equity
Disclosure of subsidiaries [line items]
Equity	0	0
Holding Entities
Disclosure of subsidiaries [line items]
Current assets	93	525
Long-term assets	24,078	20,142
Current liabilities	3,096	3,024
Long-term liabilities	798	693
Holding Entities | Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Holding Entities | Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	3,252	2,843
Holding Entities | Preferred equity
Disclosure of subsidiaries [line items]
Equity	0	0
Holding Entities | Preferred Limited Partners equity
Disclosure of subsidiaries [line items]
Equity	718	516
Other Subsidiaries
Disclosure of subsidiaries [line items]
Current assets	3,639	2,816
Long-term assets	32,433	29,508
Current liabilities	2,351	3,071
Long-term liabilities	13,445	12,670
Other Subsidiaries | Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Non controlling Interests	8,129	6,298
Other Subsidiaries | Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Other Subsidiaries | Preferred equity
Disclosure of subsidiaries [line items]
Equity	0	0
Other Subsidiaries | Preferred Limited Partners equity
Disclosure of subsidiaries [line items]
Equity	0	0
Consolidating adjustments
Disclosure of subsidiaries [line items]
Current assets	(3,823)	(3,810)
Long-term assets	(29,817)	(25,157)
Current liabilities	(3,823)	(3,811)
Long-term liabilities	(642)	(760)
Consolidating adjustments | Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Consolidating adjustments | Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Non controlling Interests	0	0
Consolidating adjustments | Preferred equity
Disclosure of subsidiaries [line items]
Equity	0	0
Consolidating adjustments | Preferred Limited Partners equity
Disclosure of subsidiaries [line items]
Equity	$ (718)	$ (516)

SUBSIDIARY PUBLIC ISSUERS (De_2

SUBSIDIARY PUBLIC ISSUERS (Details - Income Statement) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Disclosure of subsidiaries [line items]
Revenues	$ 2,982	$ 2,625	$ 2,452
Net (loss) income	403	51	40
Brookfield Renewable
Disclosure of subsidiaries [line items]
Revenues	0	0	0
Net (loss) income	62	(4)	(20)
BRP Equity
Disclosure of subsidiaries [line items]
Revenues	0	0	0
Net (loss) income	7	10	0
Finco
Disclosure of subsidiaries [line items]
Revenues	0	0	0
Net (loss) income	(1)	(1)	(1)
Holding Entities
Disclosure of subsidiaries [line items]
Revenues	0	0	1
Net (loss) income	(25)	(435)	(100)
Other Subsidiaries
Disclosure of subsidiaries [line items]
Revenues	2,983	2,625	2,451
Net (loss) income	1,305	631	558
Consolidating adjustments
Disclosure of subsidiaries [line items]
Revenues	(1)	0	0
Net (loss) income	$ (945)	$ (150)	$ (397)

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) $ in Millions, $ in Millions	Feb. 25, 2019CAD ($)	Feb. 28, 2019USD ($)	Feb. 25, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)
Disclosure of non-adjusting events after reporting period [line items]
Corporate Borrowings				$ 2,340	$ 2,557	$ 9,285
20 MW hydroelectric facility | Non Recourse Borrowings
Disclosure of non-adjusting events after reporting period [line items]
Corporate Borrowings	$ 70		$ 53
Borrowings, interest rate	4.13%		4.13%
Borrowings, maturity	2,045
413 MW portfolio of select Canadian hydroelectric
Disclosure of non-adjusting events after reporting period [line items]
Brookfield Renewable entered into an agreement to sell an additional non-controlling, percent		25.00%
Dividend recapitalization		$ 50
Economic Interest retained		50.00%