Brookfield Renewable Partners (BEP) 20-F 1 Mar 18 2017 FY Annual report (foreign) Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2017	Jun. 30, 2017
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, 2017
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	2,017
Document Fiscal Period Focus	FY
Limited Partnership units
Document And Entity Infromation [Line Items]
Entity Public Float		$ 7,459,058,727
Entity LP Units Outstanding	180,388,361
General partnership units
Document And Entity Infromation [Line Items]
Entity Public Float		109,639,773
Entity LP Units Outstanding	2,651,506
Redeemable/Exchangeable partnership units
Document And Entity Infromation [Line Items]
Entity Public Float		$ 5,361,384,061
Entity LP Units Outstanding	129,658,623

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Consolidated Statment of Income (Loss) [line items]
Revenues	$ 2,625	$ 2,452	$ 1,628
Other income	47	64	122
Direct operating costs	978	1,038	552
Management service costs	(82)	(62)	(48)
Interest expense borrowings	(632)	(606)	(429)
Share of earnings (loss) from equity-accounted investments	2	0	10
Unrealized financial instruments loss	33	4	9
Depreciation	782	781	616
Other	(28)	(38)	(63)
Income tax (expense) recovery
Current	(39)	(44)	(18)
Deferred	(49)	97	80
Total Income Tax recovery (expense)	(88)	53	60
Net (loss) income	51	40	103
Net (loss) income attributable to:
Non-controlling interests	288	251	156
Preferred limited partners' equity	28	15	1
Limited partners' equity	$ (32)	$ (36)	$ 2
Basic and Diluted earnings per LP unit	$ (0.18)	$ (0.23)	$ 0.01
Non-controlling interests [member]
Consolidated Statment of Income (Loss) [line items]
Revenues	$ 2,625	$ 2,452	$ 1,628
Participating Non-controlling Interests Operating Subsidiaries
Income tax (expense) recovery
Net (loss) income	53	65	69
Net (loss) income attributable to:
Non-controlling interests	53	65	69
General partnership interest in a holding subsidiary held by Brookfield
Income tax (expense) recovery
Net (loss) income			0
Net (loss) income attributable to:
Non-controlling interests	(1)	0	0
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Income tax (expense) recovery
Net (loss) income	(23)	(29)	1
Net (loss) income attributable to:
Non-controlling interests	(23)	(29)	1
Preferred equity
Income tax (expense) recovery
Net (loss) income	26	25	30
Net (loss) income attributable to:
Non-controlling interests	$ 26	$ 25	$ 30

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	$ 51	$ 40	$ 103
Other comprehensive income that will not be reclassified to net income
Revaluations of property, plant and equipment	872	417	1,197
Revaluations of property, plant and equipment related to equity-accounted investments	54	7	96
Actuarial (loss) gain on defined benefit plans	(2)	(2)	5
Deferred income taxes on above items	(338)	34	283
Total items that will not be reclassified to net income	1,262	388	1,015
Other comprehensive income (loss) that may be reclassified to net income
Gain (loss) arising during the period on financial instruments designated as cash-flow hedges	4	8	10
Unrealized gain on available-for-sale securities	(22)	61	0
Reclassification adjustments for amounts recognized in net (loss) income	(1)	(41)	(32)
Foreign currency translation	190	986	(1,138)
Unrealized (loss) gain on foreign currency swaps - net investment hedge	(94)	(66)	55
Deferred income taxes on above items	11	(7)	(8)
Total items that may be reclassified subsequently to net (loss) income	88	941	(1,113)
Other comprehensive income	1,350	1,329	(98)
Comprehensive income	1,401	1,369	5
Comprehensive income attributable to:
Preferred limited partners' equity	28	15	1
Limited partners' equity	494	332	(94)
Comprehensive income	1,401	1,369	5
Non-controlling interests [member]
Other comprehensive income (loss) that may be reclassified to net income
Comprehensive income	1,401	1,369	5
Comprehensive income attributable to:
Comprehensive income	1,401	1,369	5
Participating Non-controlling Interests Operating Subsidiaries
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	53	65	69
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	383	635	204
Comprehensive income attributable to:
Non-controlling interests	436	700	273
General partnership interest in a holding subsidiary held by Brookfield
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income			0
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	9	6	(2)
Comprehensive income attributable to:
Non-controlling interests	8	6	(2)
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	(23)	(29)	1
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	393	304	(87)
Comprehensive income attributable to:
Non-controlling interests	370	275	(86)
Preferred equity
Consolidated Statement Of Comprehensive Income [line items]
Net (loss) income	26	25	30
Other comprehensive income (loss) that may be reclassified to net income
Other comprehensive income	39	16	(117)
Comprehensive income attributable to:
Non-controlling interests	$ 65	$ 41	$ (87)

CONSOLIDATED STATEMENTS OF FINA

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 799	$ 223
Restricted cash	181	121
Trade receivables and other current assets	554	454
Financial instrument assets	72	55
Due from related parties	60	54
Total Current Assets	1,666	907
Financial instrument assets	113	145
Equity-accounted investments	721	206
Property, plant and equipment, at fair value	27,096	25,257
Goodwill	901	896
Deferred income tax assets	177	150
Other long-term assets	230	176
Total Assets	30,904	27,737
Current liabilities
Accounts payable and accrued liabilities	542	467
Financial instrument liabilities	184	156
Due to related parties	112	76
Current portion of long-term debt	1,676	1,034
Total Current Liabilities	2,514	1,733
Financial instrument liabilities	86	72
Long-term debt and credit facilities	10,090	9,148
Deferred income tax liabilities	3,588	3,802
Other long-term liabilities	344	310
Total Liabilities	16,622	15,065
Equity
Equity Attributable To Preferred LP Equity	616	576
Limited partners' equity	3,956	3,448
Total Equity	14,282	12,672
Total Equity And Liabilities	30,904	27,737
Non-controlling interests
Current assets
Property, plant and equipment, at fair value	27,096	25,257
Total Assets	30,904	27,737
Current liabilities
Total Liabilities	16,622	15,065
Participating Non-controlling Interests Operating Subsidiaries
Equity
Non-controlling interests	6,298	5,589
Total Equity	6,298	5,589
General partnership interest in a holding subsidiary held by Brookfield
Equity
Non-controlling interests	58	55
Total Equity	58	55
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Equity
Non-controlling interests	2,843	2,680
Total Equity	2,843	2,680
Preferred equity
Equity
Non-controlling interests	616	576
Total Equity	$ 616	$ 576

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Limited Partners' Equity	Foreign Currency Translation	Revaluation Surplus	Actuarial losses on defined benefit plans	Cash flow hedges	Available-for-sale investments	Preferred limited partners' equity	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, 2014		$ (241)	$ (241)	$ 3,685	$ (9)	$ (27)			$ 728	$ 2,062	$ 59	$ 2,865
Net (loss) income	$ 103	2	0	0	0	0		$ 1	30	69	0	1
Other comprehensive income	(98)	0	(429)	334	2	(3)		0	(117)	204	(2)	(87)
Issue Of Equity
Net proceeds	128	0	0	0	0	0		128	0	0	0	0
LP Units and preferred shares purchased for cancellation	(10)	(9)							(1)
Capital contributions	460	0								460
Distributions or dividends declared		(239)						(1)	(30)	(208)	(12)	(217)
Distribution reinvestment plan	5	5
Other	1	(3)									7	(3)
Change in period	(118)	(244)	(429)	334	2	(3)		128	(118)	525	(7)	(306)
Balance, as at at Dec. 31, 2015	8,763	(485)	(670)	4,019	(7)	(30)		128	610	2,587	52	2,559
Net (loss) income	40	(36)						15	25	65		(29)
Other comprehensive income	1,329		241	105	(1)	(1)	$ 24		16	635	6	304
Issue Of Equity
Net proceeds		657						147
Adjustment		(85)									2	83
Exchange of preferred shares								49	(49)
Capital contributions	2,621									2,621
Acquisition	1,417									1,417
Distributions or dividends declared		(281)						(15)	(25)	(119)	(24)	(232)
Distribution reinvestment plan		9
MTO adjustments		(24)	25							(1,617)
Other		(12)							(1)		19	(5)
Change in period		228	266	105	(1)	(1)	24	196	(34)	3,002	3	121
Balance, as at at Dec. 31, 2016	12,672	(257)	(404)	4,124	(8)	(31)	24	324	576	5,589	55	2,680
Net (loss) income	51	(32)						28	26	53		(23)
Other comprehensive income	1,350		26	508	(1)	2	(9)		39	383	9	393
Issue Of Equity
Net proceeds		411						187
Adjustment		(63)									1	62
Capital contributions	294									294
Acquisition	525									525
Distributions or dividends declared		(328)						(28)	(26)	(539)	(35)	(243)
Distribution reinvestment plan		10
Other		0		(16)					1	(7)	29	(26)
Change in period		(2)	26	492	(1)	2	(9)	187	40	709	3	163
Balance, as at at Dec. 31, 2017	$ 14,282	$ (259)	$ (378)	$ 4,616	$ (9)	$ (29)	$ 15	$ 511	$ 616	$ 6,298	$ 58	$ 2,843

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating activities
Net (loss) income	$ 51	$ 40	$ 103
Adjustments for the following non-cash items:
Depreciation	782	781	616
Unrealized financial instruments loss	33	4	9
Share of earnings (loss) from equity-accounted investments	2	0	10
Deferred income tax (recovery) expense	(49)	97	80
Gain on disposal	0	0	(53)
Other non-cash items	4	24	62
Dividends received from equity-accounted investments	31	6	19
Changes in due to or from related parties	(5)	(11)	18
Net change in working capital balances	25	137	62
Cash Flows From (Used In) Operating Activities	928	632	588
Financing activities
Long-term debt - borrowings	1,874	3,477	944
Long-term debt - repayments	1,607	1,975	855
Capital contributions from participating non-controlling interests - in operating subsidiaries	294	2,621	460
Acquisition of Isagen from non-controlling interests	(5)	(1,540)	0
Issuance of preferred limited partnership units	187	147	128
Issuance of LP Units	411	657	0
Repurchase of LP Units and preferred shares	0	0	10
Distributions paid:
To participating non-controlling interests - in operating subsidiaries	539	119	208
To preferred shareholders	25	25	31
To preferred limited partners' unitholders	(26)	(12)	0
To unitholders of Brookfield Renewable or BRELP	591	522	461
Cash Flows From Used In Financing Activities	(27)	2,709	(33)
Investing activities
Acquisitions	234	2,886	682
Acquisitions of equity-accounted investments	439	0	0
Cash and cash equivalents in acquired entity	611	117	19
Investment in:
Sustaining capital expenditures	(138)	(118)	(94)
Development and construction of renewable power generating assets	(217)	(251)	(191)
Capital distribution received from equity-accounted investments, net	0	0	144
Proceeds from disposal of assets	150	0	143
Investment in securities	77	60	18
Restricted cash and other	16	7	56
Cash Flows From Used In Investing Activities	(328)	(3,191)	(623)
Foreign exchange gain on cash	3	10	(19)
Cash and cash equivalents
Increase (decrease)	576	160	(87)
Balance, beginning of period	223	63	150
Balance, end of period	799	223	63
Supplemental cash flow information:
Interest paid	611	588	414
Interest received	27	40	18
Income taxes paid	48	55	32
Participating Non-controlling Interests Operating Subsidiaries
Operating activities
Net (loss) income	53	65	69
Financing activities
Capital contributions from participating non-controlling interests - in operating subsidiaries	294	2,621	460
Preferred equity
Operating activities
Net (loss) income	$ 26	$ 25	$ 30

BASIS OF PREPARATION AND SIGNIF

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2017
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, 201 7, which encompass individual IFRS, International Accounting Standards (“IAS”), and interpret ations made by the International Financial Reporting Interpretations Committee (“IFRIC”) and the Stand ard 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 its general partner, BRPL , on February 28, 2018 . Certain comparative figures have been reclassified to conform to the current year’s presentation. References to $, C$, €, R$, £, and COP are to United States (“U.S.”) dollars, Canadian dollars, Euros, Brazilian reais, British pounds sterling, and Colombian pesos, 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 Broo kfield 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 in terests 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 with 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 pa rtnership 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 R enewable’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. As Brookfield Renewable, at 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/Ex changeable 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 t o 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 - Relate d 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 c ombining 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 poolin g 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(o)(ii) - Critical judgments in applying accounting policies - Common control transactions for Broo kfield 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 joi nt 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 equit y 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, whi ch exists only 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 interest 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 pr oportionate interest in the investee. (c) 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 tha t 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 t hese operations are reported in the 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 statement 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 dete rmined and non-monetary assets measured 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 includ ed in income. (d) Cash and cash equivalents Cash and cash equivalents include cash, term deposits and money market instruments with original maturities of less than 90 days. (e) Restricted cash Restricted cash includes cash and cash equivalents, where the availability of funds is restricted primarily by credit agreements. (f) Property, plant and equipment and revaluation method Power generating assets are classified as property, plant and equipme nt and are accounted for using the revaluation method under IAS 16, Property, Plant and Equipment (“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 o f 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. 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 and capital expenditures, and assumptions about future inflation rates and discount rates by geographical location. Construction work-in-progress (“CWIP”) is reval ued 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 gen erating assets acquired through business combinations during the year, Brookfield Renewable initially measures the assets at fair value consistent with the policy described in Note 1(l) – Business combinations. Accordingly, in the year of acquisition, powe r 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 recognized in OCI and accumulated in equity under revaluation surplus and non-controlling interest. Where the carrying amount of an asset decreased, the decrease i s 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 esti mated service lives of the assets, which are as follows: 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 conditions 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 significant compo nent 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 equipment are recor ded 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 concession asset. The weighted-average remaining duration at December 31, 2017 is 15 years ( 2016 : 15 years). Since land rights are part of the concession or authorization, this cost is also subject to depreciation. Any accumulated 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 recognized in Other income in the consolidated st atements of income. The revaluation surplus is reclassified within the respective components of equity and not reclassified to net income when the assets are disposed. (g) Asset impairment At each statement of financial position date, management assesses w hether 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, determined 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 an d 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 revised estimate of the recoverable amount, and t he carrying amount that would have been recorded had no impairment loss been recognized previously. (h) Trade receivables and other current assets Trade receivables and other current assets are recognized initially at fair value, and subsequently measured at amortized cost using the effective interest method, less any allowance for uncollectability. (i) Financial instruments All financial instruments are classified into one of the following categories: assets and liabilities at fair value through profit or loss (“FVTPL”), cash, loans and receivables, financial instruments used for hedging, and other financial liabilities. All financial instruments are recorded at fair value at recognition. Subsequent to initial recognition, financial assets classified as l oans and receivables, and other financial liabilities are measured at amortized cost using the effective interest method. Financial assets and financial liabilities classified as financial instruments used for cash-flow hedging continue to be recognized at fair value through OCI. Other financial assets and financial liabilities and non-hedging financial instruments are recorded at fair value through profit and loss. Brookfield Renewable presents the liability and equity components separately upon recogniti on of such financial instruments. The amount of accretion relating to the liability component is recognized in profit or loss; and the amount of consideration relating to the equity component is recognized in equity. Brookfield Renewable selectively u tilizes derivative financial instruments to manage financial risks, including interest rate, commodity and foreign exchange risks. A derivative is a financial instrument, which requires little or no initial investment, settles at a future date, and has a v alue that changes in response to the change in a specified variable such as an interest rate, financial instrument price, commodity price, foreign exchange rate, index of prices or rates, credit rating or credit index. Hedge accounting is applied when the derivative is designated as a hedge of a specific exposure, and it is highly probable that it will continue to be effective as a hedge based on an expectation of offsetting cash flows or fair value. Hedge accounting is discontinued prospectively when the d erivative no longer qualifies as a hedge or the hedging relationship is terminated. Once discontinued, the cumulative change in fair value of a derivative that was previously recorded in equity by the application of hedge accounting is recognized in income over the remaining term of the original hedging relationship, unless the originally forecasted transaction is no longer expected to occur, at which point it is released to income. The fair values of derivative financial instruments are included in financi al instrument assets or financial instrument liabilities, respectively. (i) Items qualifying as hedges Cash flow hedge The effective portion of unrealized gains and losses on interest rate forward and swap contracts designated as hedges of future inte rest rate payments are included in equity as cash flow hedges when the interest rate risk relates to an anticipated interest payment. The periodic exchanges of payments on interest rate swap contracts designated as hedges of debt are recorded on an accrual basis as an adjustment to interest expense. The periodic exchanges of payments on interest rate contracts designated as hedges of future interest payments are recorded in income over the term of the corresponding interest payments. Net investment hedge Realized and unrealized gains and losses on foreign exchange forward contracts designated as hedges of currency risks are included in equity when the currency risk relates to a net investment in a subsidiary with a functional currency other than the U.S. d ollar and are included in income in the period in which the subsidiary is disposed. (ii) Items not qualifying as hedges Upon initial recognition of a derivative financial instrument that is not designated as a hedge, a derivative asset or liability is recorded with an offsetting deferred liability or asset, respectively. Gains or losses arising from changes in fair value of the derivative asset or liability are recognized in income through fair value gains or losses in the period the changes occur. The deferred liability or asset is amortized through income, on a straight-line basis, over the life of the derivative financial instrument. (iii) Available-for-sale investments Brookfield Renewable maintains a portfolio of marketable securities comprised of liquid equity and debt securities categorized as available-for-sale when it is not Brookfield Renewable’s strategic intent to sell the securities and the securities were not acquired principally for their near-term sale. Available-for-sale equity and debt inves tments are recorded at fair value with unrealized gains and losses recorded in OCI. Realized gains and losses are recorded in income when investments are sold and are calculated using the average carrying amount of securities sold. If the fair value of an investment declines below the carrying amount, qualitative and quantitative assessments of whether the impairment is either significant or prolonged is undertaken. All relevant facts and circumstances in this assessment are undertaken to determine, particul arly the length of time and extent to which fair value has declined below the carrying amount. In the case of significant or prolonged decline in fair value of an investment, an impairment loss is recognized. (j) Revenue and expense recognition Revenue is derived from the sale of electricity and is recorded at the time power is provided based upon the output delivered and capacity provided at rates specified under either contract terms or prevailing market rates. The revenue must be considered collectible a nd the costs incurred to provide the electricity to be measurable before recognizing the related revenue. Costs related to the purchases of power or fuel are recorded upon delivery. All other costs are recorded as incurred. (k) 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 substantively enacted at the statement of financial position dates. Current income tax assets and li abilities 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 liabi lities. Deferred tax is not recognized if the temporary difference arises from goodwill or from initial recognition (other than in a business combination) of other assets and liabilities in a transaction that affects neither taxable profit nor accounting p rofit. Deferred income tax assets are recognized for all deductible temporary differences, carry forwards of unused tax credits and unused tax losses, to the extent that it is probable that deductions, tax credits and tax losses can be utilized. The carryi ng 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 income 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. (l) Business combinations The acquisition of a business is accounted for using the acquisition 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 are recognized at their fair values at the acquisition date, except for income taxes which are measured in accordance with IAS 12, Income Taxe s , share-based payments which are measured in accordance with IFRS 2, Share-based Payment and non-current assets that are classified as held-for-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 proportion of the net fair value of the identifiable assets, liabilities and contingent liabilities recognized or when a pplicable, 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, previousl y 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. Amounts arising from interests in the acquired business p rior 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 subsidiary (including any OCI relating to the subsidiary) a re 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 acquisition includes any asset or liability resulting from a c ontingent 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 period adjustments. All other subsequent changes in the f air 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 within equity are not subsequently re-measured. (m) Other items (i) 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 materials, direct labor an d 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 wh en 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. Capitalization of costs ceases w hen the asset is ready for its intended use. (ii) Pension and employee future benefits Pension and employee future benefits are recognized in the consolidated financial statements in respect of employees of the operating entities within Brookfield R enewable. 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 best 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 financial position to reflect t he 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 cost s, 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 losses, 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 retained earnings through OCI in the period in which they occur. Re-measurements are not reclassified to profit or loss in subsequent periods. For defined contribution plans, amounts are expensed based on employee entitlement. (iii) Decommissioning, restoration and environmental liabilities Legal and constructive o bligations 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 refle cts 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 carrying amount of decommi ssioning, 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. (iv) 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. (v) Provision s 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 settle the obligation usi ng 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 rate. The increase in th e provision due to the passage of time is recognized as interest expense. (vi) Interest income Interest income is earned with the passage of time and is recorded on an accrual basis. (vii) Government grants Brookfield Renewable becomes eligible fo r 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 whether 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 grant amounts are recognize d 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 the grant is recognized as revenue in the month that delivery of the electricity occurs. (n) Critical estimates Brookfield Renewable makes estimates and assumptions that affect the carrying value of assets and liabilities, disclosure of contingent assets and 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 relate 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-term average generation, e stimated 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 assumptions in the valuatio n of Brookfield Renewable’s property, plant and equipment. See Note 1(o)(iii) - Critical judgments in applying accounting policies - Property, plant and equipment for further details. Estimates of useful lives and residual values are used in determining d epreciation 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 affect the carrying value o f 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. Non-financial instruments are valued using estimates of futur e electricity prices which are estimated by considering broker quotes for the years in which there is a liquid market and, for the subsequent years, Brookfield Renewable’s best estimate of electricity prices that would allow new entrants into the market. T he 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 pr esent value of future cash flows. See Note 5 - Risk management and financial instruments for more details. (iii) Deferred in

PRINCIPAL SUBSIDIARIES

PRINCIPAL SUBSIDIARIES	12 Months Ended
	Dec. 31, 2017
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, 2017 : 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 Power Wind Prince LP Ontario 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 Granite Reliable Power, LLC (1) Delaware 89.5 Great Lakes Hydro America, LLC Delaware 100 Great Lakes Power Limited Ontario 100 Hawks Nest Hydro LLC Delaware 100 Isagen S.A. E.S.P. (1) Colombia 99.5 Itiquira Energética S.A. Brazil 100 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 PEA - Parque Eólico da Serra, Unipessola S.A. (1) Portugal 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, 2017
Disclosure Text Block [Abstract]
BUSINESS COMBINATIONS	3 . ACQUISITIONS 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 . See Note 19 – Equity-accounted investments. European Storage In August 2017 , Brookfield Renewable, along with its institutional partners, acquired a 25 % interest in FHH Guernsey Ltd which o wns a 2.1 GW pumped storage portfolio in the United 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 lar ge 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 h ad previously accounted for its indirect interest 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 income 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 Oct ober 2017, Brookfield Renewable entered into 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 director s of the Brookfield subsidiary, thereby providing 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 au dited 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 Nort hern 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. Accordingly, if the acquisition had taken place at the beginn ing of the year, 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. Th e 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. TerraForm Global In December 2017 , along with its institutional partners, Brookf ield Renewable closed the acquisition of a 100 % interest in TerraForm Global, Inc. (“ TerraForm Global ”). TerraForm Global is 919 MW portfolio of diversified solar and wind assets located predominately in Brazil and Asia. The total consideration paid was $ 6 57 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 date totaling $ 30 mill ion. 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 for 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 gain 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. The pr ovisional purchase price allocations, at fair value, with respect t o 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 long-term debt (1,183) - (1,183) Financial instruments (15) - (15) Long-term debt (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, 2017. 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 statements 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 Bra zil (“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 contracts of R$ 24 million ($ 6 millio n). 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 income 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 B rookfield 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 audited 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 Renewable 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 t he 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 consideration 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. P urchase price allocations 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) Long-term debt (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 (Note 17) 799 - - - 799 Purchase price $ 1,926 $ 103 $ 859 $ 9 $ 2,897 Completed in 2015 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. European Wind Portfolio In February 2015 , Brookfield Renewable acquired two wind facilities in Portugal (“ Portugal Wind Portfolio ”) with an aggregate capacity of 123 MW, and expected to generate 260 GWh annually. The acquisition was completed with institutional partne rs, and Brookfield Renewable retains an approximate 40 % controlling interest. Total consideration of € 65 million ($ 71 million) included cash paid on closing of € 58 million ($ 63 million), post-closing adjustments, and deferred consideration. The revenue fo r the year ended December 31, 2015 is $ 28 million. In June 2015 , Brookfield Renewable acquired an onshore wind development pipeline in Scotland (“ Scotland Wind Pipeline ”) totaling approximately 1,200 MW, including a mix of contracted, permitted and earlier stage development projects. Total consideration of £ 47 million ($ 72 million) included upfront cash paid of £ 40 million ($ 62 million), contingent consideration, and working capital adjustments. The acquisition costs of $ 1 million were expensed as incurred. The contingent consideration was recorded at its fair value of £ 6 million ($ 9 million), which represents the present value of a probability-weighted evaluation of Brookfield Renewable’s obligation to pay up to £ 63 million ($ 97 million) related to the buil d-out of the development pipeline. The contingent consideration was recognized in the Consolidated Statements of Financial Position within the Other long-term liabilities line item. Brazil Portfolio In November 2014 , Brookfield Renewable entered into an agreement to acquire a 488 MW portfolio in Brazil comprising of hydroelectric, wind and biomass generating capacity (“Brazil Portfolio”). The acquisition s were completed in 2015 with institutional partners, and Brookfield Renewable retains an approximate 4 0 % controlling interest . Total consideration of R$ 1, 867 million ($ 5 88 milli on) included cash paid of R$ 1,717 million ($ 541 million) and deferred consideration. T he remaining non-controlling interests were subsequently acquired for R$ 50 million ($ 1 6 millio n). The total acquisition costs of $ 2 million were expensed as incurred. If the acquisition had taken place at the beginning of 2015 the revenue from the acquisition would have been $ 93 million (unaudited) for the year ended December 31, 2015. Voting Agre ements In March 2015, Brookfield Renewable entered into voting agreements with certain Brookfield subsidiaries (and their managing member s ) related to Brookfield Infrastructure Fund II (the “BIF II Entities”) which are co-investors along with a subsidiary of Brookfield Renewable in Brazilian entities (the “FIPs”) which hold the Brazil Portfol io power generating operations. Pursuant to these voting agreements, the BIF II Entities agreed to provide Brookfield Renewable, among other things, the authority to di rect the election of the manager of the jointly-owned FIPs. Purchase price allocations Final purchase price allocations, at fair values, with respect to the acquisitions are as follows: (MILLIONS) Brazil Portugal Scotland Total Cash and cash equivalents $ 19 $ - $ - $ 19 Restricted cash 16 5 - 21 Trade receivables and other current assets 16 3 1 20 Property, plant and equipment, at fair value 854 209 84 1,147 Current liabilities (21) (19) (1) (41) Long-term debt (280) (111) - (391) Other long-term liabilities - (16) (12) (28) Non-controlling interests (16) - - (16) Net assets acquired $ 588 $ 71 $ 72 $ 731 During the years ended December 31, 2017 and 2016, the purchase price allocations for the acquisitions in 2016 and 2015, respectively, were finalized. No material changes to the provisional purchase price allocations disclosed in the audited annual consolidated financial statements for 2016 and 2015 had to be considered for acquisitions made in the respective years.

DISPOSAL OF ASSETS

DISPOSAL OF ASSETS	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
DISPOSAL OF ASSETS	4 . DISPOSAL OF ASSETS In March 201 7 , along with its institutional partners , Brookfield Renewable sold its interest in two wind facilities in Ireland, with a combined capacity of 1 37 MW , to a third party . G ross cash consideration consisted of €147 million ( $ 155 million ), inclusive of working capital adjustments. The resulting loss on disposition of €5 million ( $ 5 million ), net of €5 million ( $ 5 million ) of transaction costs, was recognized in the audited annual consolidated s tatements of i ncome within Othe r. Brookfield Renewable’s interest was approximately 40 %. As a result of the disposition, the post-tax accumulated revaluation surplus of €44 million ( $ 47 million ) was reclassified from other comprehen sive income directly to equity . Further, other compreh ensive loss of €3 million ( $ 3 million ) post-tax on interest rate swaps which had been designated as hedges was reclassified to the audited annual consolidated s tatements of i ncome . Summarized financial information relating to the disposal of the facilities is s hown below: (MILLIONS) Net proceeds, including working capital adjustments and transaction costs $ 150 Carrying value Assets 353 Liabilities (198) 155 Loss on disposal $ (5)

RISK MANAGEMENT AND FINANCIAL I

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2017
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 five percent with all other variables held con stant. 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) 2017 2016 2015 2017 2016 2015 5% increase $ (3) $ (1) $ (2) $ (4) $ (7) $ (7) 5% decrease 3 1 2 4 7 7 (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 th e 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 of changes 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. Impact 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) 2017 2016 2015 2017 2016 2015 5% increase $ 4 $ 1 $ 2 $ 79 $ 51 $ 10 5% decrease (4) (1) (2) (79) (51) (10) Amounts represent the potential annual net pretax impact. Amounts represent the potential annual net pretax impact. Amounts represent the potential annual net pretax impact. (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 Renewabl e’s variable rate debt, which is limited to certain subsidiary borrowings with a total principal value of $ 4,176 million ( 2016 : $ 4,194 million). Of this princ ipal value, $ 824 million ( 2016 : $ 966 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 impac t 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 ra te swaps and variable rate debt, for the year ended December 31: Effect on net income (1) Effect on OCI (1) (MILLIONS) 2017 2016 2015 2017 2016 2015 1% increase $ 17 $ (17) $ (15) $ 54 $ 115 $ 125 1% decrease (17) 17 15 (54) (115) (125) (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 and diversifi cation 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 having long st anding credit histories or investment grade ratings, which limit the risk of non-collection. See Note 22 - Trade receivables and other current assets, for additional details regarding Brookfield Renewable’s trade receivables balance. The maximum credit exposure at December 31 was as follows: (MILLIONS) 2017 2016 Cash and cash equivalents $ 799 $ 223 Restricted cash (1) 284 250 Trade receivables and other short-term receivables 442 365 Financial instrument assets (1) 185 200 Due from related parties 60 54 $ 1,770 $ 1,092 Includes both the current and long-term amounts. (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 – Long-term debt and credit facilities. Brookfield Renewable also e nsur es that it has access to public capital markets and maintain s a strong investment grade cre dit rating. Brookfield Renewable 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 Th e table below classifies the 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 undiscounted 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, 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 Long-term debt and credit facilities (1) 1,676 4,587 5,579 11,842 Interest payable on long-term debt (2) 634 1,924 1,697 4,255 Total $ 3,149 $ 6,576 $ 7,310 $ 17,035 AS AT DECEMBER 31, 2016 (MILLIONS) < 1 year 2-5 years > 5 years Total Accounts payable and accrued liabilities $ 467 $ - $ - $ 467 Financial instrument liabilities (1) 156 66 6 228 Due to related parties 76 - - 76 Other long-term liabilities - concession payments 1 4 11 16 Long-term debt and credit facilities (1) 1,034 3,970 5,256 10,260 Interest payable on long-term debt (2) 589 1,821 1,449 3,859 Total $ 2,323 $ 5,861 $ 6,722 $ 14,906 (1) Includes both the current and long-term amounts. (2) Represents aggregate interest payable expected to be paid over the entire term of the obligations, if held to maturity. Variable rate interest payments h ave been calculated based on estimated interest rates. Brookfield Renewable classifies its assets and liabilities as outlined below: Other Non-financial Cash, loans Derivatives financial assets and AS AT DECEMBER 31, 2017 and Assets/ used for assets and non-financial (MILLIONS) receivables liabilities (1) hedging liabilities liabilities Total Cash and cash equivalents $ 799 $ - $ - $ - $ - $ 799 Restricted cash 181 - - - - - 181 Trade and other receivables (2) 442 - - - - 442 Other current assets - - - - 112 112 Due from related parties (2) 60 - - - - 60 Financial instrument assets (3) - 20 6 159 - 185 Equity-accounted investments - - - - 721 721 Property, plant and equipment, at fair value - - - - 27,096 27,096 Goodwill - - - - 901 901 Deferred income tax assets - - - - 177 177 Other long-term assets 103 - - - 127 230 Total assets $ 1,585 $ 20 $ 6 $ 159 $ 29,134 $ 30,904 Accounts payable and accrued liabilities (2) $ - $ - $ - $ 542 $ - $ 542 Financial instrument liabilities (3) - 145 125 - - 270 Due to related parties (2) - - - 112 - 112 Long-term debt and credit facilities (2)(3) - - - 11,766 - 11,766 Deferred income tax liabilities - - - - 3,588 3,588 Other long-term liabilities - - - 344 - 344 Total liabilities $ - $ 145 $ 125 $ 12,764 $ 3,588 $ 16,622 Measured at fair value with all gains and losses recorded in the consolidated statement of income . Measured at fair value at inception and subsequently recorded at amortized cost using the effective interest rate method. Includes both the current and long-term amounts. Other Non-financial Cash, loans Derivatives financial assets and AS AT DECEMBER 31, 2016 and Assets/ used for assets and non-financial (MILLIONS) receivables liabilities (1) hedging liabilities liabilities Total Cash and cash equivalents $ 223 $ - $ - $ - $ - $ 223 Restricted cash 121 - - - - 121 Trade and other receivables (2) 365 - - - - 365 Other current assets - - - - 89 89 Due from related parties (2) 54 - - - - 54 Financial instrument assets (3) - 14 50 136 - 200 Equity-accounted investments - - - - 206 206 Property, plant and equipment, at fair value - - - - 25,257 25,257 Goodwill - - - - 896 896 Deferred income tax assets - - - - 150 150 Other long-term assets 129 - - - 47 176 Total assets $ 892 $ 14 $ 50 $ 136 $ 26,645 $ 27,737 Accounts payable and accrued liabilities (2) $ - $ - $ - $ 467 $ - $ 467 Financial instrument liabilities (3) - 11 217 - - 228 Due to related parties (2) - - - 76 - 76 Long-term debt and credit facilities (2)(3) - - - 10,182 - 10,182 Deferred income tax liabilities - - - - 3,802 3,802 Other long-term liabilities - - - 310 - 310 Total liabilities $ - $ 11 $ 217 $ 11,035 $ 3,802 $ 15,065 Measured at fair value with all gains and losses recorded in the consolidated statement of income. Measured at fair value at inception and subsequently recorded at amortized cost using the effective interest rate method. Includes both the current and long-term amounts. 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 r ates, 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 asse t. 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 – inputs are bas ed 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 2017 2016 Assets measured at fair value: Cash and cash equivalents $ 799 $ - $ - $ 799 $ 223 Restricted cash (1) 284 - - 284 250 Financial instrument assets (2) Energy derivative contracts - - - - 8 Interest rate swaps - 6 - 6 7 Foreign exchange swaps - 20 - 20 49 Available-for-sale investments (2) 79 80 - 159 136 Property, plant and equipment - - 27,096 27,096 25,257 Liabilities measured at fair value: Financial instrument liabilities (3) Energy derivative contracts - (19) - (19) (5) Interest rate swaps - (155) - (155) (178) Foreign exchange swaps - (96) - (96) (45) Contingent consideration (4) - - (18) (18) (16) Liabilities for which fair value is disclosed: Long-term debt and credit facilities - (12,479) - (12,479) (10,870) Total $ 1,162 $ (12,643) $ 27,078 $ 15,597 $ 14,816 Includes both the current amount and long-term amount included in Other long-term assets. Includes amounts in Level 2 that relate to the Brookfield Infrastructure Debt Fund holdings. Includes both current and long-term amounts. Amount relates to 2015 and 2014 business combinations with obligations lapsing in 2021 and 2024 respectively. There were no transfers between levels during the year ended December 31, 2017 . Financial instruments disclosures The aggregate amount of Brookfield Renewable’s net financial instrument positions as at December 31 are as follows: 2017 2016 Net Liabilities Net Liabilities (MILLIONS) Assets Liabilities (Assets) (Assets) Energy derivative contracts $ - $ 19 $ 19 $ (3) Interest rate swaps 6 155 149 171 Foreign exchange swaps 20 96 76 (4) Available-for-sale securities 159 - (159) (136) Total 185 270 85 28 Less: current portion 72 184 112 101 Long-term portion $ 113 $ 86 $ (27) $ (73) The following table presents the change in Brookfield Renewable’s total net financial instrument liability position as at and for the year ended December 31: (MILLIONS) Note 2017 2016 2015 Balance, beginning of year $ 28 $ 145 $ 77 Increases (decreases) in the net financial instrument liability position: Unrealized loss (gain) through income on energy derivative contracts (a) 5 - (2) Unrealized loss through OCI on energy derivative contracts (a) 17 28 3 Unrealized (gain) loss through income on interest rate swaps (b) (1) 7 (2) Unrealized (gain) loss through OCI on interest rate swaps (b) (18) 1 20 Unrealized loss (gain) through income on foreign exchange swaps (c) 29 (3) 13 Unrealized loss (gain) through OCI on foreign exchange swaps (c) 94 61 (57) Unrealized loss through income on available-for-sale investments (d) - - 25 Unrealized loss (gain) through OCI on available-for-sale investments (d) 20 (52) - Acquisitions, settlements and other (89) (159) 68 Balance, end of year $ 85 $ 28 $ 145 Financial instrument liabilities not designated as hedging instruments: Energy derivative contracts (a) $ 5 $ 3 $ - Interest rate swaps (b) 107 2 - Foreign exchange swaps (c) 33 6 - Net positions $ 145 $ 11 $ - Financial instrument liabilities designated as hedging instruments: Energy derivative contracts (a) $ 14 $ 2 $ 1 Interest rate swaps (b) 48 176 178 Foreign exchange swaps (c) 63 39 12 Net positions $ 125 $ 217 $ 191 Financial instrument assets not designated as hedging instruments: Energy derivative contracts (a) $ - $ (3) $ - Interest rate swaps (b) (1) (1) - Foreign exchange swaps (c) (19) (10) (1) Available-for-sale investments (d) (159) (136) (14) Net positions $ (179) $ (150) $ (15) Financial instrument assets designated as hedging instruments: Energy derivative contracts (a) $ - $ (5) $ (31) Interest rate swaps (b) (5) (6) - Foreign exchange swaps (c) (1) (39) - Net positions $ (6) $ (50) $ (31) Total net positions $ 85 $ 28 $ 145 (a) 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. For the year ended December 31, 2017 , gains of $ 23 million relating to energy derivative contracts were realized and reclassified from OCI to revenues in the consolidated statements of income (loss) ( 2016 : $ 48 million and 2015 : $ 32 million). Based on market prices as of December 31, 2017 , unrealized losses of $ 9 million ( 2016 : $ 6 million gains and 2015 : $ 25 million gains ) recorded in accumulated other comprehensive income (“AOCI”) 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. (b) Interest rate hedges Brookfield Renewable has entered into interest rate hedge contracts primarily to minimize exposure to i nterest 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. At December 31, 2017 , agreements with a total notional exposure of $ 1,704 million were outstanding ( 2016 : $ 2,397 million) including $ 780 million ( 2016 : $ 871 million) associated with agreements that are not formally designated as hedging instruments. The weighted-average fixed interest r ate resulting fr om these agreements is 4.5 % ( 2016 : 2.5 %). For the year ended December 31, 2017 , net movements relating to cash flow hedges realized and reclassified from OCI to interest expense – borrowings in the consolidated statements of income (loss) were $ 2 0 million losses ( 2016 : $ 16 million and 2015 : $nil). Based on market prices as of December 31, 2017 , unrealized losses of $ 18 million ( 2016 : $ 110 million and 2015 : $ 114 million) recorded in AOCI on interest rate swaps a re 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 rates. (c) 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. At December 31, 2017 , ag reements with a total notional exposure of $ 2,306 million were outstanding ( 2016 : $ 1,325 million) including $ 718 million ( 2016 : $ 283 million) associated with agreements that are not formally designated as hedging instruments. Based on market prices as of December 31, 2017 , unrealized losses of $ 48 million ( 2016 : $ 1 million and 2015 : $ 12 million) recorded in AOCI on foreign exchange swaps 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 rates. (d) Available-for-sale Brookfield Renewable’s available for sale assets consist of investments in liquid equity and debt securities. Available-for-sale securities are recorded on the statement of financial position at fair value, and are assessed for impairment at each reporting date. For the year ended December 31, 2017 , net movements relating to a vailable-for-sale securities reali zed and reclassified from OCI to net income were $ 2 million gains ( 2016 : $ 9 million gains and 2015 : $nil).

SEGMENTED INFORMATION

SEGMENTED INFORMATION	12 Months Ended
	Dec. 31, 2017
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 th e type of technology. W ith effect f rom the fourth quarter of 2017, operations are segmented by technology – 1) hydroelectric, 2) wind, 3) solar, storage, and other (Co-gen and biomass), and 4) corporate – with hydroelectric and wind further segmented by g eography (Nor th America, Colombia, Brazil, Europe and Other ). To reflect the way in which the CODM now reviews results, manage operations and allocate resources, f ollowing the investments in European Storage , TerraForm Power and TerraForm Global and as Brookfield Renewable continue s to build out its solar and storage businesses, the CODM has commenced reviewing these businesses along with its Co-gen and biomass businesses on an aggregate basis . The Colombia segment aggregates the financial results of its hydroele ctric and Co-gen facilities. A pumped storage facility in North America, that was previously included in the hydroelectric segment, is now included in the “Solar, storage and other” segment. The corporate segment represents all activity performed above the individual segments for the business. In addition, with the effect from the fourth quarter of 2017, the reporting to the CODM such that the measures utilized by the CODM to assess performance and allocate resources are on a proportionate basis. Informati on 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 control s or exercise s significant influence or joint control over the inve stment, 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 results 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 di sclosed. 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 (1) include Brookfield Re newable’s proportionate share of earnings from equity-accounted investments attributable to each of the above-noted items, and (2) exclude the proportionate share of earnings (loss) of consolidated investments not held by us apportioned to each of the abov e-noted items. Segmented net income (loss) is not a measure the CODM uses to review the results of business and allocate resources. Brookfield Renewable do es not control those entities that have not been consolidated and as such, have been presented as equ ity-accounted investments in its financial statements. The presentation of the assets and liabilities and revenues and expenses do not represent Brookfield Renewable’s legal claim to such items, and the removal of financial statement amounts that are attri butable 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 consist ent manner. 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. The accounting policies of the reportable segments are th e same as those described in Note 1 – Basis of preparation and significant accounting policies. Brookfield Renewable analyzes the performance of its operati ng segments based on revenues, A djusted 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. As compared to the preceding years, Brookfield Renewable revised its definition of Adjus ted EBITDA to include its proportionate share of Adjusted EBITDA from equity-accounted investments. In preceding years, Brookfield Renewable included its proportionate shares of Funds From Operations from equity-accounted investments. Brookfield Renewable revised its definition as it believe s it provides a more meaningful measure for investors to evaluate financial and operating performance on an allocable basis to Unitholders. Brookfield Renewable uses Funds From Operations to assess the performance of its business 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 and distributions to preferred shareholders and preferred limited partner s. The following segmented information is regularly reported to the CODM. 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 , 2017 : Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Solar, Corporate Total equity to non- As per North North Storage and accounted controlling IFRS ($ MILLIONS) America Colombia Brazil America Europe Brazil Other investments interests financials (1) Revenues 945 191 243 161 46 26 67 - 1,679 (74) 1,020 2,625 Other income 1 2 12 - - - 6 19 40 (11) 18 47 Direct operating costs (281) (94) (77) (42) (20) (4) (34) (25) (577) 28 (429) (978) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 57 - 57 Adjusted EBITDA 665 99 178 119 26 22 39 (6) 1,142 - 609 - Management service costs - - - - - - - (82) (82) - - (82) Interest expense - borrowings (180) (42) (18) (45) (10) (6) (17) (89) (407) 21 (246) (632) Current income taxes 1 (5) (12) - (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 52 148 74 15 16 21 (231) 581 - - - Depreciation (222) (26) (141) (89) (24) (8) (29) - (539) 22 (265) (782) Unrealized financial instrument loss (3) (3) - (1) (12) - - (10) (29) 1 (5) (33) Deferred income tax expense (67) (10) 2 45 6 - 1 (3) (26) (3) (20) (49) Other (20) 6 (8) (3) (5) 2 (6) (9) (43) 13 2 (28) 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) 174 19 1 26 (20) 10 (13) (253) (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 $53 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests . Net income (loss) attributable to Unithol ders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limited partners equity and pre ferred equity. The following table provides each segment’s results in the format that management organizes its segments to make operating decisions and assess performance and reconciles Brookfield Renewable’s proportionate results to our consolidated statements of income on a line by line basis by aggregating the components comprising the earnings from Brookfield Renewable’s investments in associates and reflecting the portion of each line item attributable to non-controlling interests for the year ended December 31 , 2016 : Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Colombia Brazil America Europe Brazil Other investments interests financials (1) Revenues 819 192 187 151 56 17 58 1 1,481 (37) 1,008 2,452 Other income 24 3 13 - - - (1) 8 47 - 17 64 Direct operating costs (295) (107) (70) (36) (24) (4) (26) (24) (586) 16 (468) (1,038) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 21 - 21 Adjusted EBITDA 548 88 130 115 32 13 31 (15) 942 - 557 - Management service costs - - - - - - - (62) (62) - - (62) Interest expense - borrowings (177) (36) (24) (41) (14) (7) (12) (91) (402) 12 (216) (606) Current income taxes (4) (6) (9) - - - - - (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 46 97 74 18 6 19 (208) 419 - - - Depreciation (244) (31) (125) (80) (38) (4) (18) - (540) 11 (252) (781) Unrealized financial instrument loss 1 - - - - - 2 (6) (3) (2) 1 (4) Deferred income tax expense 31 6 7 49 6 - - (21) 78 - 19 97 Other (27) 4 (5) 4 6 (1) (2) 2 (19) - (19) (38) 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 25 (26) 47 (8) 1 1 (233) (65) - - (65) 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 , 2015: Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Colombia Brazil America Europe Brazil Other investments interests financials (1) Revenues 819 - 203 150 56 9 59 - 1,296 (44) 376 1,628 Other income 23 - 28 12 8 - - 5 76 - 46 122 Direct operating costs (285) - (67) (38) (20) (1) (31) (23) (465) 18 (105) (552) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 26 - 26 Adjusted EBITDA 557 - 164 124 44 8 28 (18) 907 - 317 - Management service costs - - - - - - - (48) (48) - - (48) Interest expense - borrowings (179) - (18) (48) (12) (3) (5) (81) (346) 6 (89) (429) Current income taxes (5) - (10) - - - - - (15) - (3) (18) Distributions attributable to Preferred limited partners equity - - - - - - - (1) (1) - - (1) Preferred equity - - - - - - - (30) (30) - - (30) Share of interest and cash taxes from equity accounted investments - - - - - - - - - (6) - (6) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - (225) (225) Funds From Operations 373 - 136 76 32 5 23 (178) 467 - - - Depreciation (218) - (113) (83) (32) (4) (12) - (462) 9 (161) (614) Unrealized financial instrument loss 1 - - 2 - - (1) (15) (13) 1 3 (9) Deferred income tax recovery 36 - 4 16 2 - - 20 78 - 2 80 Other 14 - (8) (30) (1) - (4) (39) (68) - - (68) Share of earnings from equity accounted investments - - - - - - - - - (10) - (10) Net income attributable to non-controlling interests - - - - - - - - - - 156 156 Net income (loss) attributable to Unitholders (2) 206 - 19 (19) 1 1 6 (212) 2 - - 2 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 Corporate Total equity to non- Total North North Storage and accounted controlling (MILLIONS) America Colombia Brazil America Europe Brazil Other Other investments interests As at December 31, 2017: Property, plant and equipment, at fair value $ 11,396 $ 1,303 $ 1,908 $ 1,798 $ 482 $ 304 $ 11 $ 1,227 $ - $ 18,429 $ (1,451) $ 10,118 $ 27,096 Total assets 11,709 1,574 2,149 1,888 532 443 31 1,456 180 19,962 (1,040) 11,982 30,904 Total borrowings 3,049 447 200 1,005 233 192 9 752 2,552 8,439 (848) 4,175 11,766 Total liabilities 5,237 801 380 1,338 334 208 18 877 2,786 11,979 (1,039) 5,682 16,622 For the year ended December 31, 2017: Additions to property, plant and equipment 90 8 59 6 34 - - 13 10 220 (10) 144 354 As at December 31, 2016: Property, plant and equipment, at fair value $ 10,922 $ 1,273 $ 1,895 $ 1,327 $ 545 $ 139 $ - $ 491 $ - 16,592 $ (428) $ 9,093 $ 25,257 Total assets 11,219 1,577 2,059 1,389 587 153 - 561 182 17,727 (280) 10,290 27,737 Total borrowings 2,946 467 194 727 249 50 - 215 2,229 7,077 (232) 3,337 10,182 Total liabilities 5,414 824 340 990 337 51 - 268 2,418 10,642 (280) 4,703 15,065 For the year ended December 31, 2016: Additions to property, plant and equipment 86 9 79 3 18 1 - 18 8 222 (10) 146 358 Geographical Information The following table presents consolidated revenue split by geographical region: (MILLIONS) 2017 2016 2015 United States $ 871 $ 786 $ 799 Colombia 797 819 - Canada 480 442 426 Brazil 366 269 265 Europe 111 136 138 2,625 2,452 1,628 The following table presents consolidated property, plant and equipment and equity-accounted investments split by geographical region: (MILLIONS) 2017 2016 United States $ 11,131 $ 10,163 Colombia 5,401 5,275 Canada 5,810 5,845 Brazil 3,479 2,922 Europe 1,332 1,258 Other 664 - 27,817 25,463

OTHER INCOME

OTHER INCOME	12 Months Ended
	Dec. 31, 2017
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) 2017 2016 2015 Interest income and other $ 32 $ 41 $ 21 Gain on available for sale investments (Note 3) 15 - - Gains on settlement of foreign currency contracts - 23 31 Gain on disposal (1) - - 53 Compensation related to expired Brazilian concession agreements (2) - - 17 $ 47 $ 64 $ 122	[1],[2]
[1]	In 2015, concession agreements relating to two Brazilian hydroelectric facilities expired. Brookfield Renewable elected not to renew these agreements in exchange for compensation of $17 million.
[2]	In 2015, the sale of the 102 MW wind facility in California resulted in a gain of $53 million. Brookfield Renewable’s share of the gain was $ 12 million, representing the 22 % interest in the facility, and is net of the cash portion of non-controlling interests.

DIRECT OPERATING COSTS

DIRECT OPERATING COSTS	12 Months Ended
	Dec. 31, 2017
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 2017 2016 2015 Operations, maintenance and administration $ 567 $ 553 $ 396 Water royalties, property taxes and other 161 149 119 Fuel and power purchases (1) 226 313 15 Energy marketing fees 27 24 23 22 $ 978 $ 1,038 $ 552	[1]
[1]	F uel and power purchase s are primarily attributable to our portfolio in Colombia.

OTHER

OTHER	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
Other	9 . O THER Brookfield Renewable’s other for the year ended December 31 is comprised of the following : (MILLIONS) Notes 2017 2016 2015 Transaction costs $ (9) $ (22) $ (6) Change in fair value of property, plant and equipment 12 (33) (36) (45) Unrealized loss on available-for-sale securities - - (25) Other 14 20 13 $ (28) $ (38) $ (63)

FOREIGN CURRENCY TRANSLATION

FOREIGN CURRENCY TRANSLATION	12 Months Ended
	Dec. 31, 2017
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 (loss) is comprised of the following : (MILLIONS) Notes 2017 2016 2015 Foreign currency translation on Property, plant and equipment, at fair value 12 $ 506 $ 1,186 $ (1,975) Long-term debt and credit facilities (282) (244) 697 Deferred income tax liabilities and assets (82) (157) 202 Other assets and liabilities 48 201 (62) $ 190 $ 986 $ (1,138)

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2017
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) 2017 2016 2015 Income tax (expense) recovery applicable to: Current taxes Attributed to the current period $ (39) $ (44) $ (18) Deferred taxes Income taxes - origination and reversal of temporary differences $ 8 $ 71 $ 87 Relating to change in tax rates / imposition of new tax laws (42) 35 6 Relating to unrecognized temporary differences and tax losses (15) (9) (15) $ (49) $ 97 $ 78 Total income tax (expense) recovery $ (88) $ 53 $ 60 The major components of deferred income tax recovery (expense) for the year ended December 31 recorded directly to OCI are as follows: (MILLIONS) 2017 2016 2015 Deferred income taxes attributed to: Financial instruments designated as cash flow hedges $ (4) $ 2 $ 8 Other 15 (7) (17) Revaluation surplus Origination and reversal of temporary differences (248) (55) (263) Relating to changes in tax rates / imposition of new tax laws 586 19 (19) $ 349 $ (41) $ (291) 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) 2017 2016 2015 Statutory income tax (expense) recovery (1) $ (50) $ 5 $ (15) (Reduction) increase resulting from: Increase in tax assets not recognized (15) (9) (15) Deemed profit method differences in Brazil 1 (11) 10 Differences between statutory rate and future tax rate (38) 54 68 Income or losses recorded not taxable to Brookfield Renewable 14 14 14 Other - - (2) Effective income tax (expense) recovery $ (88) $ 53 $ 60 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 63.31 % for the year ended December 31, 2017 ( 2016 : 384.03 %). The effective tax rate is more than the statutory rate primarily due to rate diffe rentials, 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) 2017 2016 2018 to 2022 $ 8 $ - 2023 and thereafter 108 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: Amount available Difference Net deferred Non-capital for future between tax and tax (liabilities) (MILLIONS) losses deductions carrying value assets As at January 1, 2015 $ 403 $ 88 $ (2,986) $ (2,495) Recognized in Net income (loss) 73 (11) 16 78 Recognized in equity (1) - (279) (280) Business combination 5 - (35) (30) Foreign exchange (22) (12) 223 189 As at December 31, 2015 458 65 (3,061) (2,538) Recognized in Net income (loss) 24 (10) 83 97 Recognized in equity 17 - (48) (31) Business combination - - (1,020) (1,020) Foreign exchange - 1 (161) (160) As at December 31, 2016 499 56 (4,207) (3,652) Recognized in Net income (loss) (97) (5) 53 (49) Recognized in equity 13 - 341 354 Business combination 79 - (63) 16 Foreign exchange 14 4 (98) (80) As at December 31, 2017 $ 508 $ 55 $ (3,974) $ (3,411) The deferred income tax liabilities include $ 2,561 million ( 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 $ 1,549 million ( 2016 : $ 1,380 million). As a result of the recent U.S. income tax reform, Brookfield Renewable 's net deferred tax liability decreased by $ 546 million, of which $ 41 million was recorded as a tax expense in net income and $ 587 million was recorded as a tax recovery in other comprehensive income. Over the long term, it is expected that the decrease in the U.S. federal income tax rate to reduce our overall effective tax rate.

PROPERTY, PLANT AND EQUIPMENT,

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE	12 Months Ended
	Dec. 31, 2017
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 Hydroelectric Wind Other (1) Total (2) As at December 31, 2014 $ 15,210 $ 3,315 $ 41 $ 18,566 Additions 183 51 55 289 Acquisitions through business combinations 3 307 624 229 1,160 Disposal - (230) - (230) Items recognized through OCI Change in fair value 1,141 52 16 1,209 Foreign exchange (1,585) (336) (54) (1,975) Items recognized through net income Change in fair value (2) (43) - (45) Depreciation (407) (200) (9) (616) 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 - 618 627 1,245 Disposal 4 - (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 $ 3,751 $ 946 $ 27,096 Includes solar, storage, biomass and Co-gen. Includes intangible assets of $ 13 million (201 6 : $ 1 4 million and 2015: $ 13 million ) and construction work in process (“CWIP”) of $ 601 million (201 6 : $ 663 million and 2015: $ 405 million ). The fair value of Brookfield Renewable’s property, plant and equipment is calculated as described in Not es 1 ( f ) - Property, plant and equipment and revaluation method and 1 ( n ) - Critical estimate s. Judgment is involved in determining the appropriate estimates and assumptions in the valuation of Brookfield Renewable’s property, plant and equipment. See Note 1 ( o ) (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 2017 2016 2017 2016 2017 2016 2017 2016 Discount rate Contracted 4.9% - 6.0% 4.8% - 5.5% 11.3% N/A 8.9% 9.2% 4.1% - 4.5% 4.1% - 5.0% Uncontracted 6.5% - 7.6% 6.6% - 7.2% 12.6% N/A 10.2% 10.5% 5.9% - 6.3% 5.9% - 6.8% Terminal capitalization rate (1) 6.2% - 7.5% 6.3% - 6.9% 0.126 N/A N/A N/A NA N/A Exit date 2037 2036 2037 N/A 2032 2031 2031 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: 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) (50) - - (230) 25 bps decrease in terminal capitalization rate (1) 190 50 - - 240 2016 North (MILLIONS) America Colombia Brazil Europe Total 25 bps increase in discount rates $ (670) $ N/A $ (50) $ (20) $ (740) 25 bps decrease in discount rates 730 N/A 50 20 800 5% increase in future electricity prices 540 N/A 70 20 630 5% decrease in future electricity prices (540) N/A (70) (20) (630) 25 bps increase in terminal capitalization rate (1) (180) N/A - - (180) 25 bps decrease in terminal capitalization rate (1) 190 N/A - - 190 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 C olombia . 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 without consideration of potential renewal value. The weighted-average remaining duration of the authorization or useful life of a concession as set at December 31, 2017 , is 15 years ( 2016 : 15 years). Consequently, there is no terminal value attributed to the hydroelectric assets in Brazil . If an additional 20 years of cash flows were included in Brazil , the fair value of property, plant and equipment would increase by approximately $ 1 ,500 million. The following table summarizes the percentage of total generation contracted under power purchase agreements as at December 31, 2017 : North America Colombia Brazil Europe 1 - 10 years 58% 17% 66% 78% 11 - 20 years 42% - 57% 35% 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 $ 84 COP 211,000 R$ 274 € 90 11 - 20 years 88 - 407 107 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 $ 63 COP 238,000 R$ 309 € 78 11 - 20 years 112 339,000 458 95 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 2021 and 2025. A further one year change would increase or decrease the fair value of property, plant and equipment by approximately $160 million ( 2016 : $130 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) 2017 2016 Hydroelectric $ 12,740 $ 12,761 Wind 3,030 2,688 Solar and other (1) 933 319 $ 16,703 $ 15,768 Includes biomass and Co-gen.

LONG-TERM DEBT AND CREDIT FACIL

LONG-TERM DEBT AND CREDIT FACILITIES	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
LONG-TERM DEBT AND CREDIT FACILITIES	13 . LONG-TERM DEBT AND CREDIT FACILITIES The composition of debt obligations as at December 31 is p resented in the following table: 2017 2016 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 Corporate borrowings Series 3 (C$200) 5.3 0.8 $ 159 $ 163 5.3 1.8 $ 149 $ 158 Series 4 (C$150) 5.8 18.9 119 144 5.8 19.9 111 132 Series 7 (C$450) 5.1 2.8 358 382 5.1 3.8 334 368 Series 8 (C$400) 4.8 4.1 318 344 4.8 5.1 298 331 Series 9 (C$400) 3.8 7.4 318 321 3.8 8.4 298 308 Series 10 (C$500) 3.6 9.0 398 400 3.6 10.0 372 380 4.5 6.4 $ 1,670 $ 1,754 4.5 7.4 $ 1,562 $ 1,677 Credit facilities 2.6 4.5 $ 887 $ 887 1.9 4.5 $ 673 $ 673 Subsidiary borrowings Hydroelectric 6.3 8.8 $ 6,392 6,813 6.9 7.8 $ 6,249 6,600 Wind 5.8 9.7 2,211 2,343 4.6 13.1 1,735 1,879 Solar and other 11.0 8.2 682 682 8.9 18.8 41 41 6.5 9.0 $ 9,285 $ 9,838 6.4 9.0 $ 8,025 $ 8,520 Total debt 11,842 12,479 10,260 10,870 Add: Unamortized premiums (1) 1 2 Less: Unamortized financing fees (1) (77) (80) Less: Current portion (2)(3) (1,676) (1,034) $ 10,090 $ 9,148 Unamortized premiums and unamortized financing fees are amortized to interest expense over the terms of the borrowing As part of the TerraForm Global transaction, Brookfield Renewable acquired $841 million of borrowings that were immediately classified as current due to the change of control provision allowing the holders to direct TerraForm Global to redeem the bonds at 101% of par value in the first quarter of 2018. Brookfield Renewable redeemed these borrowings at approximately 107% of par value in the first quarter of 2018 with a combination of available cash on hand and proceeds from note offering that closed on February 22, 2018. See Note 20 – Cash and Cash Equivalents and Note 31 – Subsequent Events. As part of the TerraForm Global transaction, Brookfield Renewable acquired project level financings that were in default prior to the acquisition, had outstanding principal amounts totaling $342 million and mature in 2031. See Note 18 – Capital Management. . The following table outlines changes in Brookfield Renewable’s borrowings for the year ended December 31: Cash flows from Non-cash (MILLIONS) Jan 1 financing activities Acquisition Disposal Other (1) Dec 31 2017 $ 10,182 $ 267 $ 1,188 $ (173) $ 302 $ 11,766 2016 $ 7,338 $ 1,502 $ 1,104 $ - $ 238 $ 10,182 Includes foreign exchange and amortization of unamortized premium and financing fees. Future repayments of Brookfield Renewable’s debt obligations, for each of the next five years and thereafter are as follows: (MILLIONS) 2018 2019 2020 2021 2022 Thereafter Total Corporate borrowings and credit facilities $ 159 $ 202 $ 377 $ - $ 984 $ 835 $ 2,557 Subsidiary borrowings Hydro 206 366 1,013 822 317 3,668 6,392 Wind 665 115 122 125 132 1,052 2,211 Solar and other 646 3 3 2 4 24 682 $ 1,676 $ 686 $ 1,515 $ 949 $ 1,437 $ 5,579 11,842 Equity-accounted investments $ 110 $ 116 $ 112 $ 716 $ 602 $ 3,003 $ 4,659 $ 16,501 Subsidiary borrowings and corporate borrowings and credit facilities include $1 million and $77 million of unamortized premiums and deferred financing fees, respectively. The following table outlines change in financing fees for the year ended December 31: (MILLIONS) 2017 2016 2015 Corporate borrowings Unamortized financing fees, beginning of year $ 6 $ 5 $ 5 Additional financing fees - 2 1 Amortization of financing fees (1) (1) (1) Unamortized financing fees, end of year $ 5 $ 6 $ 5 Subsidiary borrowings Unamortized financing fees, beginning of year $ 74 $ 54 $ 66 Additional financing fees 16 41 7 Amortization of financing fees (14) (17) (15) Foreign exchange translation and other (4) (4) (4) Unamortized financing fees, end of year $ 72 $ 74 $ 54 Total $ 77 $ 80 $ 59 Corporate borrowings 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 payable by Finco are unconditionally guara nteed by Brookfield Renewable, Brookfield Renewable Energy L.P. (“BRELP”) and certain other subsidiaries. Our sole near time maturity is our C$ 200 million ($ 159 million) Series 3 medium-term notes which mature in November 2018 . Subsidiary borrowings Subsid iary borrowings are typically asset-specific, long-term, non-recourse borrowings denominated in the domestic currency of the subsidiary. Subsidiary borrowings in North America, Europe and South Africa consist of both fixed and floating interest rate debt. Subsidiary borrowings in South Africa consist of floating interest rate debt indexed to the Johannesburg Interbank Agreed Rate (“JIBAR”) and U.S. dollar denominated debt indexed to the London Interbank Offered Rate (“LIBOR”). Brookfield Renewable uses inte rest rate swap agreements in North America, Europe and South Africa to minimize its exposure to floating interest rates. Subsidiary borrowings in Brazil consist of floating interest rates of Taxa de Juros de Longo Prazo (“TJLP”), the Brazil National Bank f or Economic Development’s long-term interest rate, or Interbank Deposit Certificate rate (“CDI”), plus a margin. Subsidiary borrowings in Colombia include floating interest rates of Indicador Bancario de Referencia rate (“IBR”), the Banco Central de Colomb ia short-term interest rate, or Colombian Consumer Price Index (“IPC”), the Banco Central de Colombia inflation rate, plus a margin. Subsidiary borrowings in Malaysia consist of floating interest rate debt indexed to the Kuala Lumpur Interbank Offering Rat e (“KLIBOR”). Subsidiary borrowings in India consist of fixed interest rate U.S. dollar denominated debt. In March 2017, Brookfield Renewable completed the refinancing of a $ 60 million bank loan associated with a 417 MW hydroelectric facility in Pennsylvan ia. The loan bears interest at LIBOR plus a margin of 3.75 % and matures in March 2022 . In May 2017, Brookfield Renewable completed the refinancing associated with a 44 MW hydroelectric portfolio in New England by issuing notes for $ 65 million. The notes c arry a 4.86 % coupon rate and mature in May 2027 . In June 2017, Brookfield Renewable completed the refinancing associated with a 11 MW wind asset in Arizona by securing a $ 11 million bank loan. The loan has been fully hedged for an all-in rate of 5.28 % and matures in June 2024 . In June 2017, Brookfield Renewable completed the financing associated with a 17 MW hydroelectric facility in Quebec by issuing notes for C$ 55 million ($ 43 million). The notes bear an all-in rate of 4.49 % and mature in May 2044 . In July 2017, Brookfield Renewable completed the refinancing of a 360 MW hydroelectric portfolio in New England. The financing was a $ 475 million green bond bearing interest at 4.4 % with a maturity in July 2032 . In October 2017, Brookfield Renewable com pleted financing associated with a 47 MW portfolio of wind farms in Ireland by securing € 78 million ($ 92 million) of long-term debt, € 6 million ($ 8 million) working capital facility and € 4 million ($ 4 million) debt reserve facility. The long-term debt matu res in 2032 and bears interest at EURIBOR plus a margin of 1.5 %. In December 2017, Brookfield Renewable completed a $ 305 million refinancing, associated with an 872 MW portfolio of hydroelectric facilities in New York at an all-in interest rate of 4.29 % an d with a maturity in December 2030 . In December 2017, Brookfield Renewable completed a £ 17 million ($ 22 million) non-recourse financing associated with a 16 MW wind asset in Northern Ireland. The long-term debt matures in 2035 and bears interest at GBP LIB OR plus a margin of 2.20 % . In December 2017 , Brookfield Renewable completed R$ 166 million ($ 50 million) of financing with respect to a 28 MW hydroelectric facility currently under construction in Brazil. The loan bears interest at a rate of TJLP plus 2.12 % and matures in 2038 . C redit facilities In June 201 7 , Brookfield Renewable extended the maturity of $ 1,6 0 0 million of its corporate credit facilities by one year to June 30, 202 2 . T he applicable margin is 1.20 % . T he credit facilities are used for general working capital purposes and issuing letters of credit. The credit facilities bear interest at the applicable banker’s acceptance rate, LIBOR or EURIBOR plus an applicable margin. The applicable margin is tiered on the basis of Brookfield Renewable’s u nsec ured long-term debt rating. During the first quarter of 2017, the committed unsecured revolving credit facility provided by Brookfield Asset Management was increased to $ 4 00 million . During the fourth quarter of 2017, Brookfield Renewable exte nded the maturi ty by one year t o December 201 8 . I nterest rate applicable on the draw s is LIBOR plus 2 %. Brookfield Renewable and its subsidiaries issue letters of credit from some of their credit facilities for general corporate purposes which include, but are not limited to, security deposits, performance bonds and guarantees for debt service reserve accoun ts. The following table summarizes the available portion of credit facilities as at December 31: (MILLIONS) 2017 2016 Authorized credit facilities $ 2,090 $ 1,890 Draws on credit facilities (1) (685) (673) Issued letters of credit (193) (250) Available portion of credit facilities $ 1,212 $ 967

NON-CONTROLLING INTERESTS

NON-CONTROLLING INTERESTS	12 Months Ended
	Dec. 31, 2017
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) 2017 2016 Participating non-controlling interests - in operating subsidiaries $ 6,298 $ 5,589 General partnership interest in a holding subsidiary held by Brookfield 58 55 Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield 2,843 2,680 Preferred equity 616 576 $ 9,815 $ 8,900 Participating non-controlling interests – in operating subsidiaries The net change in participating non-controlling interests – in operating subsidiaries is as follows: Isagen Brookfield Isagen public Americas Brookfield Brookfield The institu- non-con Infrastructure Infrastructure Infrastructure Catalyst tional -trolling (MILLIONS) Fund Fund II Fund III Group investors interests Other Total As at December 31, 2014 $ 914 $ 937 $ - $ 126 $ - $ - $ 85 $ 2,062 Net income 26 27 - 14 - - 2 69 OCI 89 144 - (12) - - (17) 204 Capital contributions - 460 - - - - - 460 Distributions (70) (126) - (7) - - (5) (208) Other (1) (1) - - - - 2 - As at December 31, 2015 $ 958 $ 1,441 $ - $ 121 $ - $ - $ 67 $ 2,587 Net (loss) 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 Interests held by third parties 75-80% 50-60% 23-71% 25% 53% 0.5% 21-50% T he privatization of the Isagen portfolio was completed on March 31, 2017 and its shares were delisted from the Colombia Stock Exchange . D uring the year ended December 31, 2017 , Brookfield Renewable, together with its co-investors , acquired an additional 3,358,523 shares in Isagen. In accordance with IFRS 10, Consolidated Financial Statements , Brookfield Renewable is accounting for the additional interests in Isagen purchased subsequent to the initial investments as equity transact ions related to the acquisition of non-controlling interest. As at December 31, 2017 Brookfield Renewable together with its co-investors owns approximately 99.5 % interest in Isagen. T he remaining approximately 0.5 % ownership interest not held by B rookfield Renewable and it s co-investors remains as non-controlling interest. 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 Infrastructure Infrastructure Infrastructure The Catalyst (MILLIONS) Fund Fund II Fund III (1) Group Isagen (2) Other Total Interests held by third parties 75-80% 50-60% 69-71% 25% 76% 21-50% Place of business United States, Brazil United States, Brazil, Europe United States, Brazil, India, China, South Africa United States Colombia United States, Brazil, Canada For the year ended December 31, 2015: Revenue $ 136 $ 402 $ - $ 160 $ - $ 30 $ 728 Net income 34 49 - 56 - 8 147 Total comprehensive income (loss) 144 247 - 8 - (51) 348 Net income allocated to non-controlling interests 26 27 - 14 - 2 69 For the year ended December 31, 2016: Revenue $ 118 $ 394 $ 28 $ 164 $ 819 $ 27 $ 1,550 Net (loss) income (22) (23) (8) 62 110 5 124 Total comprehensive income (loss) 37 356 (8) 70 502 31 988 Net (loss) income allocated to non-controlling interests (18) (16) (5) 16 86 2 65 As at December 31, 2016: Property, plant and equipment, at fair value $ 1,807 $ 4,816 $ 848 $ 970 $ 5,275 $ 417 $ 14,133 Total assets 1,865 5,125 855 1,072 6,539 428 15,884 Total borrowings 571 1,881 313 450 1,924 41 5,180 Total liabilities 631 2,235 319 466 3,396 60 7,107 Carrying value of non- controlling interests $ 963 $ 1,654 $ 383 $ 127 $ 2,391 $ 71 $ 5,589 For the 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 (loss) income (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 Excludes information relating to Isagen which is presented separately. The total third parties ownership interest in Isagen as of December 31, 2017 was 75.9 % and comprised of Brookfield Infrastructure Fund III: 22.9 %, Isagen Institutional investors 52.5 % and Isagen public 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 , 2017 , general partnership units, and Redeemable/Exchangeable partnership units outstanding were 2,651,506 (December 31, 2016 : 2,651,506 ) and 129,658,623 (December 31, 2016 : 129,658,623 ), respective ly. Distributions The composition of the distributions for the year ended December 31 is presented in the following table: (MILLIONS) 2017 2016 General partnership interest in a holding subsidiary held by Brookfield $ 5 $ 5 Incentive distribution 30 19 $ 35 $ 24 Participating non-controlling interests - in a holding subsidiary - Redeemable/ Exchangeable units held by Brookfield $ 243 $ 232 $ 278 $ 256 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) 2017 2016 2015 For the year ended December 31 : Revenue $ 2,625 $ 2,452 $ 1,628 Net income 51 40 103 Comprehensive income 1,401 1,369 5 Net income allocated to (1) : GP interest (1) - - Redeemable/Exchangeable partnership units (23) (29) 1 As at December 31 : Property, plant and equipment, at fair value $ 27,096 $ 25,257 Total assets 30,904 27,737 Total borrowings 11,766 10,182 Total liabilities 16,622 15,065 Carrying value of (2) : GP interest 58 55 Redeemable/Exchangeable partnership units 2,843 2,680 Allocated based on weighted-average GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 173.5 million, respectively ( 2016 : 2.7 million, 129.7 million, and 1 56.4 million, respectively and 2015 : 2.7 million, 129.7 million, and 143.3 million, respectively). Allocated based on outstanding GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 180.4 million, respectively ( 2016 : 2.7 million, 129.7 million, and 166.8 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 Cumulative permitted for the year ended (MILLIONS EXCEPT Shares dividend redemption December 31 AS NOTED) outstanding rate (%) date 2017 2016 2017 2016 Series 1 (C$136) 5.45 3.36 Apr 30, 2020 $ 4 $ 3 $ 108 $ 101 Series 2 (C$113) (1) 4.51 3.63 Apr 30, 2020 3 3 90 84 Series 3 (C$249) 9.96 4.40 Jul 31, 2019 8 8 197 185 Series 5 (C$103) 4.11 5.00 Apr 30, 2018 4 4 82 76 Series 6 (C$175) 7.00 5.00 Jul 31, 2018 7 7 139 130 31.03 $ 26 $ 25 $ 616 $ 576 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, 201 7 , none of the issued Class A Preference Shares have been redeemed by BRP Equity. Class A Preference Shares – Normal Course Issuer Bid In June 2017, 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, 2018, 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 our Class A Preference Shares.

PREFERRED LIMITED PARTNERS EQUI

PREFERRED LIMITED PARTNERS EQUITY	12 Months Ended
	Dec. 31, 2017
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 LP Units as follows: Earliest Distributions declared Cumulative permitted for the year ended (MILLIONS EXCEPT Shares distribution redemption December 31 AS NOTED) outstanding rate (%) date 2017 2016 2017 2016 Series 5 (C$72) 2.89 5.59 Apr 30, 2018 $ 4 $ 3 $ 49 $ 49 Series 7 (C$175) 7.00 5.50 Jan 31, 2021 8 7 128 128 Series 9 (C$200) 8.00 5.75 Jul 31, 2021 8 5 147 147 Series 11 (C$250) 10.00 5.00 Apr 30, 2022 8 - 187 - 27.89 $ 28 $ 15 $ 511 $ 324 On February 14, 2017, Brookfield Renewable issued 10,000,000 Class A, Series 11 Preferred Limited Partnership Units (the “Series 11 Preferred Units”) at a price of C$ 25 per unit for gross proceeds of C$ 250 million ($ 190 million). The holders of the Series 11 Preferred Units are entitled to receive a cumulative quarterly fixed distribution yielding 5.0% for the initial period ending April 30, 2022 . Thereafter, the distribution rate will be reset every five years at a rate equal to the greater of: (i) the 5-year Government of Canada bond yield plus 3.82 %, and (ii) 5.00%. The holders of Series 11 Preferred Units will have the right, at their option, to convert their Series 11 Preferred Units into Class A Preferred Limited Partnership Units, Series 12 (th e “Series 12 Preferred Units”), subject to certain conditions, on April 30, 2022 and on April 30 every five years thereafter. The holders of Series 12 Preferred Units will be entitled to receive floating rate cumulative preferential cash distributions e qua l to the sum of the 90-day Canadian Treasury Bill Rate plus 3.82 % .

LIMITED PARTNERS EQUITY

LIMITED PARTNERS EQUITY	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
LIMITED PARTNERS EQUITY	(MILLIONS) 2017 2016 Brookfield $ 101 $ 83 External LP Unitholders 227 198 $ 328 $ 281 In February 2017, unitholder distributions were increased to $ 1.87 per LP Unit on an annualized basis, an increase of nine cents per LP Unit, which took effect with the distribution payable in March 2017.

GOODWILL

GOODWILL	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
GOODWILL	17 . GOODWILL The following table provides a reconciliation of goodwill: (MILLIONS) 2017 2016 Balance, beginning of year $ 896 $ - Acquired through business acquisition - 799 Foreign exchange 5 97 Balance, end of year $ 901 $ 896

CAPITAL MANAGEMENT

CAPITAL MANAGEMENT	12 Months Ended
	Dec. 31, 2017
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 which is calculated as total debt plus deferred income tax liabilities, net of deferred income tax assets, and equity. The ratio as at December 31, 2017 was 40% ( 2016 : 38%). 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. Subsidiaries of Brookfield Renewable have provided covenants to certain of their lenders for their property-specific borrowings. These covenants vary from one credit agreement to another and include ratios that address debt service coverage. Certain lende rs 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 limitation 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 tra nsaction, Brookfield Renewable acquired assets with project level financings that were in default prior to the acquisition, had outstanding principal amounts totaling $ 342 million and mature in 2031 . As at December 31, 2017, the loans were not in complia nce with certain covenants due to the SunEdison Bankruptcy, as well as issues with contractors under the engineering, procurement and construction contract. The loan balances have been classified as current as at December 31, 2017. Brookfield Renewable is currently working with all the lenders to cure such defaults and release the res trictions placed on the projects. Except for the aforementioned defaults, Brookfield Renewable complied with all material financial covenants as of December 31, 2017 . Brookfield Renewa ble’s strategy during 2017, which was unchanged from 2016, was to maintain the measure set out in the following schedule as at December 31: (MILLIONS) 2017 2016 Total debt Current portion of long-term debt (1) $ 1,676 $ 1,034 Long-term debt and credit facilities 10,090 9,148 11,766 10,182 Deferred income tax liabilities, net (2) 3,411 3,652 Equity 14,282 12,672 Total capitalization $ 29,459 $ 26,506 Debt to total capitalization 40% 38%	[1]
[1]	As part of the TerraForm Global transaction, Brookfield Renewable acquired $ 841 million of borrowings that were immediately classified as current due to the change of control provision allowing the holders to direct TerraForm Global to redeem the bonds at 101 % of par value in the first quarter of 2018. Brookfield Renewable redeemed these borrowings at approximately 107 % of par value in the first quarter of 2018 with a combination of available cash on hand and proceeds from note offering th at closed on February 22, 2018. See Note 20 – Cash and Cash Equivalents and Note 31 – Subsequent Events Deferred income tax liabilities less deferred income tax assets.

EQUITY-ACCOUNTED INVESTMENTS

EQUITY-ACCOUNTED INVESTMENTS	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
EQUITY-ACCOUNTED INVESTMENTS	19 . EQUITY-ACCOUNTED INVESTMENTS The following are Brookfield Renewable’s equity-accounted investments as at December 31: Principal place Ownership Carrying value of business interest (MILLIONS) % 2017 2016 FHH (Guernsey) Limited Europe 25 $ 245 $ - TerraForm Power Inc. (1) United States, Canada 16 212 - Bear Swamp Power Co. L.L.C. United States 50 173 114 Galera Centrais Eletricas S.A. Brazil 50 28 29 Pingston Power Inc. Canada 50 57 58 Brookfield Infrastructure Fund II Investees United States, Europe 14 - 50 6 5 $ 721 $ 206 The following table outlines the changes in Brookfield Renewable’s equity-accounted investments for the year ended December 31: (MILLIONS) 2017 2016 2015 Balance, beginning of year $ 206 $ 197 $ 273 Share of net income 2 - 10 Share of OCI Revaluation of property, plant and equipment 54 7 96 Other 2 1 - Dividends declared (31) (6) (19) Capital distributions, net - - (144) Acquisition of European Storage (Note 3) 248 - - Acquisition of TerraForm Power (Note 3) 221 - - Foreign exchange translation 19 7 (19) Balance, end of year $ 721 $ 206 $ 197 The following tables summarize certain financial information of equity-accounted investments: (MILLIONS) 2017 2016 As at December 31: Current assets $ 477 $ 45 Property, plant and equipment, at fair value 8,098 864 Other assets 213 70 Current liabilities 687 42 Long-term debt 4,294 463 Other liabilities 958 71 (MILLIONS) 2017 2016 2015 For the year ended December 31 Revenue $ 310 $ 74 $ 89 Net (loss) income (24) - 19 Share of net income (loss) Cash earnings 29 9 20 Non-cash loss (27) (9) (10)

CASH AND CASH EQUIVALENTS

CASH AND CASH EQUIVALENTS	12 Months Ended
	Dec. 31, 2017
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: Cash (1) $ 790 $ 210 Short-term deposits 9 13 $ 799 $ 223

RESTRICTED CASH

RESTRICTED CASH	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
RESTRICTED CASH	21 . RESTRICTED CASH Brookfield Renewable’s restricted cash as at December 31 is as follows: (MILLIONS) Note 2017 2016 Operations $ 195 $ 135 Credit obligations 85 104 Development projects 4 11 Total 284 250 Less: non-current 23 (103) (129) Current $ 181 $ 121

TRADE RECEIVABLES AND OTHER CUR

TRADE RECEIVABLES AND OTHER CURRENT ASSETS	12 Months Ended
	Dec. 31, 2017
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) 2017 2016 Trade receivables $ 360 $ 262 Other short-term receivables 82 103 Prepaids and others 112 89 $ 554 $ 454 As at December 31, 2017 , 99 % ( 2016 : 95 %) of trade receivables were current. 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 receivables and the credit worthiness of the counterparties. Management also reviews trade receivable balances on an ongoing basis. Bad debt expense related to trade receivables is recognized at the time an account is deemed uncollectible. Accordingly, as at December 31, 2017 and 2016 an allowance for doubtful accounts for trade receivables was not deemed necessary .

OTHER LONG-TERM ASSETS

OTHER LONG-TERM ASSETS	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
OTHER LONG-TERM ASSETS	23 . OTHER LONG-TERM ASSETS The composition of Brookfield Renewable’s other long-term assets as at December 31 is presented in the following table : Accumulated Cost Amortization Net Book Value Net book value (MILLIONS) 2017 2016 Restricted cash $ 103 $ - $ 103 $ 129 Unamortized financing fees 32 (27) 5 6 Acquisition downpayment 46 - 46 - Other 82 (6) 76 41 $ 263 $ (33) $ 230 $ 176 At December 31, 2017 and 2016 , restricted cash was held primarily to satisfy lease payments and credit agreements.

ACCOUNTS PAYABLE AND ACCRUED LI

ACCOUNTS PAYABLE AND ACCRUED LIABILITIES	12 Months Ended
	Dec. 31, 2017
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) 2017 2016 Operating accrued liabilities $ 271 $ 147 Accounts payable 117 87 Interest payable on corporate and subsidiary borrowings 64 68 Deferred consideration 35 55 Acquisition related provisions - 54 LP Unitholders’ distributions, preferred limited partnership unit distributions and preferred dividends payable (1) 29 24 Other 26 32 $ 542 $ 467	[1]
[1]	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, 2017
Disclosure Text Block [Abstract]
OTHER LONG-TERM LIABILITIES	25 . OTHER LONG-TERM LIABILITIES Brookfield Renewable’s other long-term liabilities as at December 31 are comprised of the following: (MILLIONS) Notes 2017 2016 Acquisition related provisions $ 80 $ 111 Pension obligations 29 89 87 Decommissioning retirement obligations 85 47 Contingent consideration 3 18 16 Commitments for power purchase agreements 13 - Concession payment liability 9 10 Deferred revenue 9 7 Other 41 32 $ 344 $ 310 Brookfield Renewable has recorded decommissioning retirement obligations associated with certain power generating assets. The decommissioning retirement obligation has been established for hydroelectric and wind operation sites in North America 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.

COMMITMENTS, CONTINGENCIES AND

COMMITMENTS, CONTINGENCIES AND GUARANTEES	12 Months Ended
	Dec. 31, 2017
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 extendable up to 2091 . The remaining development project costs on two Brazilian hydroelectric projects totaling 47 MW and one 28 MW wind project in Europe are expected to be $ 44 milli on. All three projects are expected to be fully operational in 2018 . As at December 31, 2017 , Brookfield Renewable had commitments for future minimum lease payments under non-cancellable leases which fall due as follows: (MILLIONS) 2018 $ 33 2019 32 2020 31 2021 30 2022 27 Thereafter 262 Total $ 415 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 – Long-term debt and credit facilities. Brookfield Renewable along with institutional investors ha s provided letters of credit, which include, but are not limited to, guarantees for debt service reserves, capital reserves, construction completion and performance as it relates to interests in the Brookfield Americas Infrastructure Fund and the Brookfield Infrastructure Fund II. Brookfield Renewable’s subsidiaries have similarly provided let ters of credit, which include, but are not limited to, guarantees for debt service reserves, capital reserves, construction completion and performance . As at December 31, l etters of credit issued by Brookfield Renewable along with institutional investors and its subsidiaries were as follows: (MILLIONS) 2017 2016 Brookfield Renewable along with institutional investors $ 76 $ 66 Brookfield Renewable's subsidiaries 468 483 $ 544 $ 549 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, 2017
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 distributions 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 exceed 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 ove rsight 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 calculated as a percen tage 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 December 31, 2017 is $ 14 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, 2017 of $ 82 million (2016: $ 62 million and 2015: $ 48 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 th e right to direct all eligible votes in the election of the directors of BRELP’s general partner. Revenue Agreements Contract Amendments In 2011, 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 support the price that GLPL receives for energy generated by certain facilities in Canada at a price of C$ 82 per MWh subject to an annual adjustment equal to 40 % of the Consumer Price Index (“CPI”) in the previous year. The GLPL agreement has an initial term to 2029 , and the contract automatically renews for successive 20-year periods with certain termination provisions. If the contract is not terminated prior to 2029, the price under this agreement reverts back to the original C$ 68 per MWh subject to an annual adjustment equal to 40% of the CPI for each year. The amended MPT power purchase agreement requires Brookfield to purchase the energy generated at a price of C$ 103 per MWh subject to an annual adjustment equal to 20 % of the CPI in the previous year . The MPT contract terminates on December 1, 2029 and MPT has been granted the unilateral option to terminate the agreement, on 120 days written notice, at certain times between 2017 and 2024. Energy Revenue Agreement In 2011, an agreement was entered int o between Brookfield and Brookfield Power U.S. Holdings America Co. (“BPUSHA”) that indirectly owns substantially all of the U.S. facilities of Brookfield Renewable. Brookfield will support the price that BPUSHA receives for energy generated by certain fac ilities in the United States at a price $ 75 per MWh. This price is to be increased annually on January 1 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. This agreement will have an initial term of 20 years, with automatic renewals for successive 20 -year periods with certain termination provisions. Other Revenue Agreements Pursuant to a 20 -year power purchase agreement, Brookfield purchases all energy from sever al power facilities in Maine and New Hampshire held by Great Lakes Holding 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. 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 %. Pursuant t o a power guarantee agreement, Brookfield 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 year. 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 t o 2029 and automatically renews for successive 20 -year period with certain termination provisions. Pursuant to a 10 -year Wind Levelization 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 Ren ewable. Power Services Agreements 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 Agreem ent, Brookfield will be entitled to be reimbursed for any third-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. 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 infla tion factor beginning on January 1, 2013). See Note 8 - Direct operating costs. Voting Agreements Brookfield Renewable entered into voting agreements with Brookfield whereby Brookfield, as managing member of entities related to the Brookfield Americ as 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 B AIF 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 Brookfield 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, agreed 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 generating operations with inst itutional 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 Entities are between 24 % and 31 %. Th e 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 Brookfield Renewable. Brookfie ld 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 Hydro Holdings’ limited partner ship 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 into a voting agreement with t he 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 providing Brookfield Renewable with significant influence over this subsidiary. Brookfield Asset Management has provided a $400 million committed unsecured revolving credit facility maturing in December 2018. See Note 13 – Long-term debt and credit facilities for further details. Brookfield Asset Management had also placed funds on deposit with Brookfield Renewable in the amount of $140 million during the first quarter of the current year, which was repaid prior to the end of the first quarter. The interest expense on the draws from the credit facility and the deposit totaled $1 million. In 2011, on formation of Brookfield Renewable, Brookfield Asset Management transferred certain development projects to Brookfield Renewable for no upfront consideration but is entitled to receive variable consideration on commercial opera tion or sale of these projects. An amount of $8 million has been paid relating to the commissioning of a 25 MW hydroelectric facility in Brazil. The following table reflects the related party agreements and transactions in the consolidated statements of income , for the year ended December 31: (MILLIONS) 2017 2016 2015 Revenues Power purchase and revenue agreements $ 601 $ 527 $ 469 Wind levelization agreement 6 8 6 $ 607 $ 535 $ 475 Direct operating costs Energy purchases $ (13) $ (3) $ (5) Energy marketing fee (24) (23) (22) Insurance services (19) (20) (30) $ (56) $ (46) $ (57) Management service costs $ (82) $ (62) $ (48) 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 2017 2016 Current assets Due from related parties Amounts due from Brookfield $ 54 $ 47 Equity-accounted investments and other 6 7 $ 60 $ 54 Current liabilities Due to related parties Amount due to Brookfield $ 48 $ 48 Accrued distributions payable on LP Units and Redeemable/Exchangeable partnership units Brookfield 32 26 Amount due to Equity-accounted investments and other 32 2 $ 112 $ 76 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, 2017
Disclosure Text Block [Abstract]
SUPPLEMENTAL INFORMATION	28 . 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) 2017 2016 2015 Trade receivables and other current assets $ (40) $ 30 $ (72) Accounts payable and accrued liabilities 32 (160) 2 Other assets and liabilities (17) (7) 8 $ (25) $ (137) $ (62)

PENSION AND EMPLOYEE FUTURE BEN

PENSION AND EMPLOYEE FUTURE BENEFITS	12 Months Ended
	Dec. 31, 2017
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 2015 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: Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans 2017 2016 2015 (%) (%) (%) Discount rate 2.4 - 7.3 3.7 - 7.1 2.2 - 7.3 4.1 - 7.3 2.9 - 4.7 4.2 - 4.7 Rate of price inflation 1.5 - 3.5 N/A 1.5 - 3.5 N/A 2.0 - 2.5 N/A Rate of compensation increases 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 3.0 2.5 - 3.0 Health care trend rate (1) N/A 5.3 - 6.9 N/A 5.3 - 6.9 N/A 6.3 - 7.1 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, 2017 , 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 (11) (4) 50 basis point decrease 13 5 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 4 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. Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Current service costs $ 3 $ 1 $ 3 $ 1 $ 3 $ 1 Past service costs (recovery) (1) - - - 1 (1) Interest expense 2 3 2 3 1 2 Administrative expenses 1 - 1 - 1 - Recognized in consolidated statement of income 5 4 6 4 6 2 Remeasurement of the net defined benefit liability: Return on plan assets (8) - (2) - (1) - Actuarial changes arising from changes in demographic assumptions 1 (2) (1) (1) 2 (5) Actuarial changes arising from changes in financial assumptions 7 3 5 1 (2) (1) Experience adjustments - 1 - - 2 - Recognized in consolidated statement of comprehensive income - 2 2 - 1 (6) Total $ 5 $ 6 $ 8 $ 4 $ 7 $ (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: Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Present value of defined benefit obligation $ 172 $ 57 $ 158 $ 53 $ 124 $ 35 Fair value of plan assets (135) (5) (119) (5) (103) - Net liability $ 37 $ 52 $ 39 $ 48 $ 21 $ 35 Defined benefit obligations The movement in the defined benefit obligation for the year ended December 31 is as follows: Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Balance, beginning of year $ 158 $ 53 $ 124 $ 35 $ 128 $ 43 Current service cost 3 1 3 1 3 1 Past service (recovery) cost (1) - - - 1 (1) Interest expense 7 3 7 3 5 2 Remeasurement losses (gains) Actuarial changes arising from changes in demographic assumptions 1 (2) (1) (1) 2 (5) Actuarial changes arising from changes in financial assumptions 7 3 5 1 (2) (1) Experience adjustments - 1 - - 2 - Benefits paid (7) (2) (8) (2) (5) (2) Business combination - - 25 14 - - Exchange differences 4 - 3 2 (10) (2) Balance, end of year $ 172 $ 57 $ 158 $ 53 $ 124 $ 35 Expected employer’s contributions to the defined benefit plans for the year ended December 31, 2018 are $6 million. Fair value of plan assets The movement in the fair value of plan assets for the year ended December 31 is as follows: Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Balance, beginning of year $ 119 $ 5 $ 103 $ - $ 108 $ - Interest income 5 - 5 - 4 - Return on plan assets 8 - 2 - 1 - Employer contributions 5 2 7 3 5 2 Business combination - - 9 4 - - Benefits paid (7) (2) (8) (2) (5) (2) Exchange differences 5 - 1 - (10) - Balance, end of year $ 135 $ 5 $ 119 $ 5 $ 103 $ - The composition of plan assets as at December 31 is as follows: 2017 2016 (%) (%) Asset category: Cash and cash equivalents 2 5 Equity securities 54 50 Debt securities 44 44 Real estate - 1 100 100

SUBSIDIARY PUBLIC ISSUERS

SUBSIDIARY PUBLIC ISSUERS	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block [Abstract]
SUBSIDIARY PUBLIC ISSUERS	30 . 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, 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 As at December 31, 2016: Current assets $ 26 $ - $ 1,581 $ 150 $ 2,092 $ (2,942) $ 907 Long-term assets 3,779 620 - 18,415 27,250 (23,234) 26,830 Current liabilities 33 9 19 2,971 1,644 (2,943) 1,733 Long-term liabilities - - 1,556 738 12,775 (1,737) 13,332 Participating non-controlling interests - in operating subsidiaries - - - - 5,589 - 5,589 Participating non-controlling interests -in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield - - - 2,680 - - 2,680 Preferred equity - 576 - - - - 576 Preferred limited partners' equity 324 - - 324 - (324) 324 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, 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 For the year ended December 31, 2015 Revenues $ - $ - $ - $ 8 $ 1,620 $ - $ 1,628 Net income (loss) 2 - (1) (42) 235 (91) 103 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 – Long-term debt and credit facilities for additional details regarding the medium-term corporate notes issued by Finco. See Note 14 – 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, 2017
Disclosure Text Block [Abstract]
SUBSEQUENT EVENTS	31 . SUBSEQUENT EVENTS On January 16, 2018, Brookfield Renewable issued 10,000,000 Series 13 Preferred LP Units at a price of C$ 25 per unit for gross proceeds of C$ 250 million ($ 201 million). On January 19, 2018, Brookfield Renewable completed financing associated with its equity-accounted 2.1 GW pumped storage facility in the United Kingdom by securing £ 60 million ($ 83 million) of long-term debt and £ 90 million ($ 125 million) letter of credit facility. The long-term debt matures in 2021 and bears interest at LIBOR plus a ma rgin 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 Brazil. The loan bears interest at a rate of TJLP plus 2.15 % and matu res in 2038 . On February 15, 2018, Brookfield Renewable completed a refinancing associated with a 296 MW hydroelectric facility in the United States. The financing was a $ 350 million interest only green bond bearing interest at 4.5 %, maturing in 2033 . Pro ceeds were used to repay the existing principal amount of $ 315 million and the excess was distributed to investors. On February 22, 2018, TerraForm Global issued $ 400 million of senior notes at 6.13 %, maturing in March 2026 . Along with cash on the balance sheet, proceeds were used to repay the existing $ 760 million of 9.75 % senior notes due in 2022 . Additionally, TerraForm Global secured a $ 45 million revolving credit facility, maturing in February 2021 . On February 27, 2018, Brookfield Renewable completed a COP 750 bil lion ($ 262 million) bond refinancing associated with the Colombian business.

BASIS OF PREPARATION AND SIGN38

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (POLICY)	12 Months Ended
	Dec. 31, 2017
Policy Text Block [Abstract]
Statement Of IFRS 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, 201 7, which encompass individual IFRS, International Accounting Standards (“IAS”), and interpret ations made by the International Financial Reporting Interpretations Committee (“IFRIC”) and the Stand ard Interpretations Committee (“SIC”).
Disclosure Of Reclassifications Or Changes In Presentation Explanatory	The policies set out below are consistently applied to all periods presented, 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 Broo kfield 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 in terests 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 with 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 pa rtnership 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 R enewable’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. As Brookfield Renewable, at 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/Ex changeable 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 t o 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 - Relate d 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 c ombining 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 poolin g 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(o)(ii) - Critical judgments in applying accounting policies - Common control transactions for Broo kfield 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 joi nt 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 equit y 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, whi ch exists only 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 interest 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 pr oportionate 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 tha t 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 t hese operations are reported in the 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 statement 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 dete rmined and non-monetary assets measured 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 includ ed 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 restricted primarily by credit agreements.
Property, plant and equipment and revaluation method	Power generating assets are classified as property, plant and equipme nt and are accounted for using the revaluation method under IAS 16, Property, Plant and Equipment (“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 o f 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. 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 and capital expenditures, and assumptions about future inflation rates and discount rates by geographical location. Construction work-in-progress (“CWIP”) is reval ued 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 gen erating assets acquired through business combinations during the year, Brookfield Renewable initially measures the assets at fair value consistent with the policy described in Note 1(l) – Business combinations. Accordingly, in the year of acquisition, powe r 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 recognized in OCI and accumulated in equity under revaluation surplus and non-controlling interest. Where the carrying amount of an asset decreased, the decrease i s 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. Gains and losses on disposal of an item of property, plant and equipment are recognized in Other income in the consolidated st atements of income. The revaluation surplus is reclassified within the respective components of equity and not reclassified to net income when the assets are disposed.
Property, plant and equipment - Depreciation	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 co-generating (“Co-gen”) units Up to 40 years Other assets Up to 60 years
Asset impairment	At each statement of financial position date, management assesses w hether 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, determined 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 an d 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 revised estimate of the recoverable amount, and t he 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 initially at fair value, and subsequently measured at amortized cost using the effective interest method, less any allowance for uncollectability.
Financial instruments	All financial instruments are classified into one of the following categories: assets and liabilities at fair value through profit or loss (“FVTPL”), cash, loans and receivables, financial instruments used for hedging, and other financial liabilities. All financial instruments are recorded at fair value at recognition. Subsequent to initial recognition, financial assets classified as l oans and receivables, and other financial liabilities are measured at amortized cost using the effective interest method. Financial assets and financial liabilities classified as financial instruments used for cash-flow hedging continue to be recognized at fair value through OCI. Other financial assets and financial liabilities and non-hedging financial instruments are recorded at fair value through profit and loss. Brookfield Renewable presents the liability and equity components separately upon recogniti on of such financial instruments. The amount of accretion relating to the liability component is recognized in profit or loss; and the amount of consideration relating to the equity component is recognized in equity.
Hedge accounting	Brookfield Renewable selectively u tilizes derivative financial instruments to manage financial risks, including interest rate, commodity and foreign exchange risks. A derivative is a financial instrument, which requires little or no initial investment, settles at a future date, and has a v alue that changes in response to the change in a specified variable such as an interest rate, financial instrument price, commodity price, foreign exchange rate, index of prices or rates, credit rating or credit index. Hedge accounting is applied when the derivative is designated as a hedge of a specific exposure, and it is highly probable that it will continue to be effective as a hedge based on an expectation of offsetting cash flows or fair value. Hedge accounting is discontinued prospectively when the d erivative no longer qualifies as a hedge or the hedging relationship is terminated. Once discontinued, the cumulative change in fair value of a derivative that was previously recorded in equity by the application of hedge accounting is recognized in income over the remaining term of the original hedging relationship, unless the originally forecasted transaction is no longer expected to occur, at which point it is released to income. The fair values of derivative financial instruments are included in financi al instrument assets or financial instrument liabilities, respectively. (i) Items qualifying as hedges Cash flow hedge The effective portion of unrealized gains and losses on interest rate forward and swap contracts designated as hedges of future inte rest rate payments are included in equity as cash flow hedges when the interest rate risk relates to an anticipated interest payment. The periodic exchanges of payments on interest rate swap contracts designated as hedges of debt are recorded on an accrual basis as an adjustment to interest expense. The periodic exchanges of payments on interest rate contracts designated as hedges of future interest payments are recorded in income over the term of the corresponding interest payments. Net investment hedge Realized and unrealized gains and losses on foreign exchange forward contracts designated as hedges of currency risks are included in equity when the currency risk relates to a net investment in a subsidiary with a functional currency other than the U.S. d ollar and are included in income in the period in which the subsidiary is disposed. (ii) Items not qualifying as hedges Upon initial recognition of a derivative financial instrument that is not designated as a hedge, a derivative asset or liability is recorded with an offsetting deferred liability or asset, respectively. Gains or losses arising from changes in fair value of the derivative asset or liability are recognized in income through fair value gains or losses in the period the changes occur. The deferred liability or asset is amortized through income, on a straight-line basis, over the life of the derivative financial instrument.
Available-for-sale investments	Brookfield Renewable maintains a portfolio of marketable securities comprised of liquid equity and debt securities categorized as available-for-sale when it is not Brookfield Renewable’s strategic intent to sell the securities and the securities were not acquired principally for their near-term sale. Available-for-sale equity and debt inves tments are recorded at fair value with unrealized gains and losses recorded in OCI. Realized gains and losses are recorded in income when investments are sold and are calculated using the average carrying amount of securities sold. If the fair value of an investment declines below the carrying amount, qualitative and quantitative assessments of whether the impairment is either significant or prolonged is undertaken. All relevant facts and circumstances in this assessment are undertaken to determine, particul arly the length of time and extent to which fair value has declined below the carrying amount. In the case of significant or prolonged decline in fair value of an investment, an impairment loss is recognized.
Revenue recognition	Revenue is derived from the sale of electricity and is recorded at the time power is provided based upon the output delivered and capacity provided at rates specified under either contract terms or prevailing market rates. The revenue must be considered collectible a nd the costs incurred to provide the electricity to be measurable before recognizing the related revenue.
Expense recognition	Costs related to the purchases of power or fuel are recorded upon delivery. All other costs are recorded as incurred.
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 substantively enacted at the statement of financial position dates. Current income tax assets and li abilities 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 liabi lities. Deferred tax is not recognized if the temporary difference arises from goodwill or from initial recognition (other than in a business combination) of other assets and liabilities in a transaction that affects neither taxable profit nor accounting p rofit. Deferred income tax assets are recognized for all deductible temporary differences, carry forwards of unused tax credits and unused tax losses, to the extent that it is probable that deductions, tax credits and tax losses can be utilized. The carryi ng 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 income 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 acquisition 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 are recognized at their fair values at the acquisition date, except for income taxes which are measured in accordance with IAS 12, Income Taxe s , share-based payments which are measured in accordance with IFRS 2, Share-based Payment and non-current assets that are classified as held-for-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 proportion of the net fair value of the identifiable assets, liabilities and contingent liabilities recognized or when a pplicable, 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, previousl y 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. Amounts arising from interests in the acquired business p rior 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 subsidiary (including any OCI relating to the subsidiary) a re 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 acquisition includes any asset or liability resulting from a c ontingent 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 period adjustments. All other subsequent changes in the f air 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 within equity are not subsequently re-measured.
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 materials, direct labor an d 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 wh en 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. Capitalization of costs ceases w hen 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 entities within Brookfield R enewable. 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 best 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 financial position to reflect t he 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 cost s, 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 losses, 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 retained earnings through OCI in the period in which they occur. Re-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 o bligations 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 refle cts 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 carrying amount of decommi ssioning, 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 settle the obligation usi ng 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 rate. The increase in th e 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 Renewable becomes eligible fo r 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 whether 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 grant amounts are recognize d 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 the grant is recognized as revenue in the month that delivery of the electricity occurs.
Critical estimates and judgements in applying accounting policies	(n) Critical estimates Brookfield Renewable makes estimates and assumptions that affect the carrying value of assets and liabilities, disclosure of contingent assets and 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 relate 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-term average generation, e stimated 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 assumptions in the valuatio n of Brookfield Renewable’s property, plant and equipment. See Note 1(o)(iii) - Critical judgments in applying accounting policies - Property, plant and equipment for further details. Estimates of useful lives and residual values are used in determining d epreciation 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 affect the carrying value o f 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. Non-financial instruments are valued using estimates of futur e electricity prices which are estimated by considering broker quotes for the years in which there is a liquid market and, for the subsequent years, Brookfield Renewable’s best estimate of electricity prices that would allow new entrants into the market. T he 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 pr esent 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 determining 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 lia bilities 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. (o) 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 fin ancial statements: (i) Preparation of consolidated financial statements These consolidated financial statements present the financial position, results of operations and cash flows of Brookfield Renewable. Judgment is required in determining what asse ts, liabilities and transactions are recognized in the consolidated financial statements as pertaining to Brookfield Renewable’s operations. (ii) Common control transactions Common control business combinations specifically fall outside of scope of I FRS 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 realit y 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 predecess or’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 property, plan t and equipment is described in Note 1(f) - 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 equipment as op posed 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 u sing 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 reasonable 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 is determine d 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 estimates of fut ure 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 long-term est imate 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 will 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, 2023 in Euro pe, and 2021 in Brazil. Based on current supply and demand fundamentals, Brookfield Renewable revised the year of new entry in North America to 2025 from 2023. 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 plants 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 determine renewable electricity prices for hydroelectric and wind facilities. In Brazil and Colombia, the estimate of future electr icity prices is based on a similar approach as applied in North America using a forecast of the all-in cost of development. Terminal 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 without consideration of potential renewal value. Discount rates are determined each year by considering the current interest rates, av erage 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 usin g the spot rates and the available forward rates, extrapolated beyond the period available. 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 rea sonable 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(i) - Financial instruments. In applying the policy, judgments are made in applying the criteria set out in IAS 39, Financial Instruments: Recognition and Measurement (“IAS 39”), to record financial instruments at fair value through profit and loss, 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(k) - 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	Standard Description Effective date Effect on financial statements In July 2014, the IASB issued the final version of IFRS 9, Financial Instruments (“IFRS 9”). The standard reflects all phases of the financial instruments project and replaces IAS 39, Financial Instruments: Recognition and Measurement and all previous versions of IFRS 9. This standard establishes principles for the financial reporting of financial assets and financial liabilities that will present relevant and useful information to users of financial statements for their assessment of the amounts, timing and uncertainty of an entity’s future cash flows. The new standard makes several improvements to IAS 39; mostly notably adopting a principle based approach to hedge accounting. While this does not change the type of hedging relationships or the requirement to measure ineffectiveness, it simplifies the application of hedge accounting and should allow for better alignment of risk management strategies with accounting presentation. Other changes include replacing the multiple financial asset impairment models in IAS 39 with a single model based on expected credit losses on all financial assets, and replacing the existing complex classifications structure with a business model approach based on the intent and nature of the cash flows. The standard has a mandatory effective date for annual periods beginning on or after January 1, 2018, with early adoption permitted. The adoption of IFRS 9 is a significant initiative for Brookfield Renewable. Management has chosen to adopt the standard retrospectively with no restatement of comparative periods. The assessment of financial assets and liabilities under the new classification methodology has been completed. Hedging documentation has been updated for compliance with IFRS 9 and updated risk management policies and internal controls to align with the new standard. Management has also assessed the impact of the new impairment requirements for financial assets. There are no material adjustments from the adoption of the standard.
IFRS 15 [Member]
Disclosure of expected impact of initial application of new standards or interpretations [line items]
Future changes in accounting policies	Standard Description Effective date Effect on financial statements IFRS 15, Revenue from Contracts with Customers (“IFRS 15”) was issued by the IASB on May 28, 2014. IFRS 15 outlines a single comprehensive model to account for revenue arising from contracts with customers and will replace the majority of existing IFRS requirements on revenue recognition including IAS 18, Revenue, IAS 11, Construction Contracts and related interpretations. The core principle of the standard is to recognize revenue to depict the transfer of goods and services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The standard has prescribed a five-step model to apply the principles. The standard also specifies how to account for the incremental costs of obtaining a contract and the costs directly related to fulfilling a contract as well as requiring more informative and relevant disclosures. IFRS 15 applies to nearly all contracts with customers, unless covered by another standard, such as leases, financial instruments and insurance contracts. In April 2016, the IASB issued amendments to IFRS 15, which provided additional guidance on the identification of performance obligations, on assessing principal versus agent considerations and on licensing revenue. The amendments also provide additional transition relief upon initial adoption of IFRS 15 and have the same effective date as the IFRS 15 standard. The standard has a mandatory effective date for annual periods beginning on or after January 1, 2018, with early adoption permitted. The adoption of IFRS 15 is a significant initiative for Brookfield Renewable. Management has chosen to adopt the standard using the modified retrospective approach. This method results in a cumulative catch-up adjustment to equity as of January 1, 2018 as if the standard had always been in effect. Management has completed its review of material revenue streams. The majority of Brookfield Renewable’s revenue streams are within the scope of IFRS 15 and are include the sale of energy, capacity and renewable energy credits through power purchase agreements or through merchant mechanisms. Based on management’s analysis, substantially all of the contracts currently in place for the year beginning on January 1, 2018 do not contain a difference in the timing or measurement of revenue recognition under the new standard and the impact of both the cumulative catch up and ongoing revenue recognition is expected to not be material to the overall statements of Brookfield Renewable.
IFRS 16 [Member]
Disclosure of expected impact of initial application of new standards or interpretations [line items]
Future changes in accounting policies	Standard Description Effective date Effect on financial statements IFRS 16, Leases (“IFRS 16”) was issued by the IASB on January 13, 2016. IFRS 16 brings most leases onto the statement of financial position for lessees under a single model, eliminating the distinction between operating and finance leases. Lessor accounting remains largely unchanged and the distinction between operating and finance leases is retained. Under IFRS 16 a lessee recognizes a right-of-use asset and a lease liability. The right-of-use asset is treated similarly to other non-financial assets and depreciated accordingly, and the liability accrues interest. The lease liability is initially measured at the present value of the lease payments payable over the lease term, discounted at the rate implicit in the lease. Lessees are permitted to make an accounting policy election, by class of underlying asset, to apply a method like IAS 17’s operating lease accounting and not recognize lease assets and lease liabilities for leases with a lease term of 12 months or less, and on a lease-by-lease basis, to apply a method similar to current operating lease accounting to leases for which the underlying asset is of low value. IFRS 16 supersedes IAS 17, Leases and related interpretations. A lessee will apply IFRS 16 to its leases either retrospectively to each prior reporting period presented or retrospectively with the cumulative effect of initially applying IFRS 16 being recognized at the date of initial application. The standard has a mandatory effective date for annual periods beginning on or after January 1, 2019, with early adoption permitted. Management has formed its adoption working group and participated in planning sessions with Brookfield Asset Management. Management continues to evaluate the impact of IFRS 16 on the consolidated financial statements.

BASIS OF PREPARATION AND SIGN39

BASIS OF PREPARATION AND SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
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 co-generating (“Co-gen”) units Up to 40 years Other assets Up to 60 years

PRINCIPAL SUBSIDIARIES (Tables)

PRINCIPAL SUBSIDIARIES (Tables)	12 Months Ended
	Dec. 31, 2017
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 Power Wind Prince LP Ontario 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 Granite Reliable Power, LLC (1) Delaware 89.5 Great Lakes Hydro America, LLC Delaware 100 Great Lakes Power Limited Ontario 100 Hawks Nest Hydro LLC Delaware 100 Isagen S.A. E.S.P. (1) Colombia 99.5 Itiquira Energética S.A. Brazil 100 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 PEA - Parque Eólico da Serra, Unipessola S.A. (1) Portugal 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, 2017
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 long-term debt (1,183) - (1,183) Financial instruments (15) - (15) Long-term debt (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) Long-term debt (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 (Note 17) 799 - - - 799 Purchase price $ 1,926 $ 103 $ 859 $ 9 $ 2,897
Acqusitions Completed In 2015
Acqusition Tables
Final purchase price allocations, at fair values, with respect to the acquisitions are as follows:	(MILLIONS) Brazil Portugal Scotland Total Cash and cash equivalents $ 19 $ - $ - $ 19 Restricted cash 16 5 - 21 Trade receivables and other current assets 16 3 1 20 Property, plant and equipment, at fair value 854 209 84 1,147 Current liabilities (21) (19) (1) (41) Long-term debt (280) (111) - (391) Other long-term liabilities - (16) (12) (28) Non-controlling interests (16) - - (16) Net assets acquired $ 588 $ 71 $ 72 $ 731

RISK MANAGEMENT AND FINANCIAL42

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2017
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, 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 Long-term debt and credit facilities (1) 1,676 4,587 5,579 11,842 Interest payable on long-term debt (2) 634 1,924 1,697 4,255 Total $ 3,149 $ 6,576 $ 7,310 $ 17,035 AS AT DECEMBER 31, 2016 (MILLIONS) < 1 year 2-5 years > 5 years Total Accounts payable and accrued liabilities $ 467 $ - $ - $ 467 Financial instrument liabilities (1) 156 66 6 228 Due to related parties 76 - - 76 Other long-term liabilities - concession payments 1 4 11 16 Long-term debt and credit facilities (1) 1,034 3,970 5,256 10,260 Interest payable on long-term debt (2) 589 1,821 1,449 3,859 Total $ 2,323 $ 5,861 $ 6,722 $ 14,906 (1) Includes both the current and long-term amounts. (2) Represents aggregate interest payable expected to be paid over the entire term of the obligations, if held to maturity. Variable rate interest payments h ave been calculated based on estimated interest rates.
Brookfield Renewable classifies its assets and liabilities as outlined below	Other Non-financial Cash, loans Derivatives financial assets and AS AT DECEMBER 31, 2017 and Assets/ used for assets and non-financial (MILLIONS) receivables liabilities (1) hedging liabilities liabilities Total Cash and cash equivalents $ 799 $ - $ - $ - $ - $ 799 Restricted cash 181 - - - - - 181 Trade and other receivables (2) 442 - - - - 442 Other current assets - - - - 112 112 Due from related parties (2) 60 - - - - 60 Financial instrument assets (3) - 20 6 159 - 185 Equity-accounted investments - - - - 721 721 Property, plant and equipment, at fair value - - - - 27,096 27,096 Goodwill - - - - 901 901 Deferred income tax assets - - - - 177 177 Other long-term assets 103 - - - 127 230 Total assets $ 1,585 $ 20 $ 6 $ 159 $ 29,134 $ 30,904 Accounts payable and accrued liabilities (2) $ - $ - $ - $ 542 $ - $ 542 Financial instrument liabilities (3) - 145 125 - - 270 Due to related parties (2) - - - 112 - 112 Long-term debt and credit facilities (2)(3) - - - 11,766 - 11,766 Deferred income tax liabilities - - - - 3,588 3,588 Other long-term liabilities - - - 344 - 344 Total liabilities $ - $ 145 $ 125 $ 12,764 $ 3,588 $ 16,622 Measured at fair value with all gains and losses recorded in the consolidated statement of income . Measured at fair value at inception and subsequently recorded at amortized cost using the effective interest rate method. Includes both the current and long-term amounts. Other Non-financial Cash, loans Derivatives financial assets and AS AT DECEMBER 31, 2016 and Assets/ used for assets and non-financial (MILLIONS) receivables liabilities (1) hedging liabilities liabilities Total Cash and cash equivalents $ 223 $ - $ - $ - $ - $ 223 Restricted cash 121 - - - - 121 Trade and other receivables (2) 365 - - - - 365 Other current assets - - - - 89 89 Due from related parties (2) 54 - - - - 54 Financial instrument assets (3) - 14 50 136 - 200 Equity-accounted investments - - - - 206 206 Property, plant and equipment, at fair value - - - - 25,257 25,257 Goodwill - - - - 896 896 Deferred income tax assets - - - - 150 150 Other long-term assets 129 - - - 47 176 Total assets $ 892 $ 14 $ 50 $ 136 $ 26,645 $ 27,737 Accounts payable and accrued liabilities (2) $ - $ - $ - $ 467 $ - $ 467 Financial instrument liabilities (3) - 11 217 - - 228 Due to related parties (2) - - - 76 - 76 Long-term debt and credit facilities (2)(3) - - - 10,182 - 10,182 Deferred income tax liabilities - - - - 3,802 3,802 Other long-term liabilities - - - 310 - 310 Total liabilities $ - $ 11 $ 217 $ 11,035 $ 3,802 $ 15,065 Measured at fair value with all gains and losses recorded in the consolidated statement of income. Measured at fair value at inception and subsequently recorded at amortized cost using the effective interest rate method. Includes both the current and long-term amounts.
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 2017 2016 Assets measured at fair value: Cash and cash equivalents $ 799 $ - $ - $ 799 $ 223 Restricted cash (1) 284 - - 284 250 Financial instrument assets (2) Energy derivative contracts - - - - 8 Interest rate swaps - 6 - 6 7 Foreign exchange swaps - 20 - 20 49 Available-for-sale investments (2) 79 80 - 159 136 Property, plant and equipment - - 27,096 27,096 25,257 Liabilities measured at fair value: Financial instrument liabilities (3) Energy derivative contracts - (19) - (19) (5) Interest rate swaps - (155) - (155) (178) Foreign exchange swaps - (96) - (96) (45) Contingent consideration (4) - - (18) (18) (16) Liabilities for which fair value is disclosed: Long-term debt and credit facilities - (12,479) - (12,479) (10,870) Total $ 1,162 $ (12,643) $ 27,078 $ 15,597 $ 14,816 Includes both the current amount and long-term amount included in Other long-term assets. Includes amounts in Level 2 that relate to the Brookfield Infrastructure Debt Fund holdings. Includes both current and long-term amounts. Amount relates to 2015 and 2014 business combinations with obligations lapsing in 2021 and 2024 respectively.
The aggregate amount of Brookfield Renewables net financial instrument positions as at December 31 are as follows:	2017 2016 Net Liabilities Net Liabilities (MILLIONS) Assets Liabilities (Assets) (Assets) Energy derivative contracts $ - $ 19 $ 19 $ (3) Interest rate swaps 6 155 149 171 Foreign exchange swaps 20 96 76 (4) Available-for-sale securities 159 - (159) (136) Total 185 270 85 28 Less: current portion 72 184 112 101 Long-term portion $ 113 $ 86 $ (27) $ (73)
The following table presents the change in Brookfield Renewables total net financial instrument liability position as at and for the year ended December 31:	(MILLIONS) Note 2017 2016 2015 Balance, beginning of year $ 28 $ 145 $ 77 Increases (decreases) in the net financial instrument liability position: Unrealized loss (gain) through income on energy derivative contracts (a) 5 - (2) Unrealized loss through OCI on energy derivative contracts (a) 17 28 3 Unrealized (gain) loss through income on interest rate swaps (b) (1) 7 (2) Unrealized (gain) loss through OCI on interest rate swaps (b) (18) 1 20 Unrealized loss (gain) through income on foreign exchange swaps (c) 29 (3) 13 Unrealized loss (gain) through OCI on foreign exchange swaps (c) 94 61 (57) Unrealized loss through income on available-for-sale investments (d) - - 25 Unrealized loss (gain) through OCI on available-for-sale investments (d) 20 (52) - Acquisitions, settlements and other (89) (159) 68 Balance, end of year $ 85 $ 28 $ 145 Financial instrument liabilities not designated as hedging instruments: Energy derivative contracts (a) $ 5 $ 3 $ - Interest rate swaps (b) 107 2 - Foreign exchange swaps (c) 33 6 - Net positions $ 145 $ 11 $ - Financial instrument liabilities designated as hedging instruments: Energy derivative contracts (a) $ 14 $ 2 $ 1 Interest rate swaps (b) 48 176 178 Foreign exchange swaps (c) 63 39 12 Net positions $ 125 $ 217 $ 191 Financial instrument assets not designated as hedging instruments: Energy derivative contracts (a) $ - $ (3) $ - Interest rate swaps (b) (1) (1) - Foreign exchange swaps (c) (19) (10) (1) Available-for-sale investments (d) (159) (136) (14) Net positions $ (179) $ (150) $ (15) Financial instrument assets designated as hedging instruments: Energy derivative contracts (a) $ - $ (5) $ (31) Interest rate swaps (b) (5) (6) - Foreign exchange swaps (c) (1) (39) - Net positions $ (6) $ (50) $ (31) Total net positions $ 85 $ 28 $ 145
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) 2017 2016 Cash and cash equivalents $ 799 $ 223 Restricted cash (1) 284 250 Trade receivables and other short-term receivables 442 365 Financial instrument assets (1) 185 200 Due from related parties 60 54 $ 1,770 $ 1,092 Includes both the current and long-term amounts.
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) 2017 2016 2015 2017 2016 2015 5% increase $ 4 $ 1 $ 2 $ 79 $ 51 $ 10 5% decrease (4) (1) (2) (79) (51) (10) 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) 2017 2016 2015 2017 2016 2015 1% increase $ 17 $ (17) $ (15) $ 54 $ 115 $ 125 1% decrease (17) 17 15 (54) (115) (125) 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) 2017 2016 2015 2017 2016 2015 5% increase $ (3) $ (1) $ (2) $ (4) $ (7) $ (7) 5% decrease 3 1 2 4 7 7 Amounts represent the potential annual net pretax impact.

SEGMENTED INFORMATION (Tables)

SEGMENTED INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2017
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, Corporate Total equity to non- As per North North Storage and accounted controlling IFRS ($ MILLIONS) America Colombia Brazil America Europe Brazil Other investments interests financials (1) Revenues 945 191 243 161 46 26 67 - 1,679 (74) 1,020 2,625 Other income 1 2 12 - - - 6 19 40 (11) 18 47 Direct operating costs (281) (94) (77) (42) (20) (4) (34) (25) (577) 28 (429) (978) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 57 - 57 Adjusted EBITDA 665 99 178 119 26 22 39 (6) 1,142 - 609 - Management service costs - - - - - - - (82) (82) - - (82) Interest expense - borrowings (180) (42) (18) (45) (10) (6) (17) (89) (407) 21 (246) (632) Current income taxes 1 (5) (12) - (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 52 148 74 15 16 21 (231) 581 - - - Depreciation (222) (26) (141) (89) (24) (8) (29) - (539) 22 (265) (782) Unrealized financial instrument loss (3) (3) - (1) (12) - - (10) (29) 1 (5) (33) Deferred income tax expense (67) (10) 2 45 6 - 1 (3) (26) (3) (20) (49) Other (20) 6 (8) (3) (5) 2 (6) (9) (43) 13 2 (28) 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) 174 19 1 26 (20) 10 (13) (253) (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 $53 million is comprised of amounts found on Share of Funds From Operations attributable to non-controlling interests and Net Income attributable to non-controlling interests . Net income (loss) attributable to Unithol ders includes net income (loss) attributable to GP interest, Redeemable/Exchangeable partnership units and LP Units. Total net income (loss) includes amounts attributable to Unitholders, non-controlling interests, preferred limited partners equity and pre ferred equity. Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Colombia Brazil America Europe Brazil Other investments interests financials (1) Revenues 819 192 187 151 56 17 58 1 1,481 (37) 1,008 2,452 Other income 24 3 13 - - - (1) 8 47 - 17 64 Direct operating costs (295) (107) (70) (36) (24) (4) (26) (24) (586) 16 (468) (1,038) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 21 - 21 Adjusted EBITDA 548 88 130 115 32 13 31 (15) 942 - 557 - Management service costs - - - - - - - (62) (62) - - (62) Interest expense - borrowings (177) (36) (24) (41) (14) (7) (12) (91) (402) 12 (216) (606) Current income taxes (4) (6) (9) - - - - - (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 46 97 74 18 6 19 (208) 419 - - - Depreciation (244) (31) (125) (80) (38) (4) (18) - (540) 11 (252) (781) Unrealized financial instrument loss 1 - - - - - 2 (6) (3) (2) 1 (4) Deferred income tax expense 31 6 7 49 6 - - (21) 78 - 19 97 Other (27) 4 (5) 4 6 (1) (2) 2 (19) - (19) (38) 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 25 (26) 47 (8) 1 1 (233) (65) - - (65) Contribution Attributable to Unitholders from Attributable Hydroelectric Wind Storage Corporate Total equity to non- As per North North and accounted controlling IFRS ($ MILLIONS) America Colombia Brazil America Europe Brazil Other investments interests financials (1) Revenues 819 - 203 150 56 9 59 - 1,296 (44) 376 1,628 Other income 23 - 28 12 8 - - 5 76 - 46 122 Direct operating costs (285) - (67) (38) (20) (1) (31) (23) (465) 18 (105) (552) Share of Adjusted EBITDA from equity accounted investments - - - - - - - - - 26 - 26 Adjusted EBITDA 557 - 164 124 44 8 28 (18) 907 - 317 - Management service costs - - - - - - - (48) (48) - - (48) Interest expense - borrowings (179) - (18) (48) (12) (3) (5) (81) (346) 6 (89) (429) Current income taxes (5) - (10) - - - - - (15) - (3) (18) Distributions attributable to Preferred limited partners equity - - - - - - - (1) (1) - - (1) Preferred equity - - - - - - - (30) (30) - - (30) Share of interest and cash taxes from equity accounted investments - - - - - - - - - (6) - (6) Share of Funds From Operations attributable to non-controlling interests - - - - - - - - - - (225) (225) Funds From Operations 373 - 136 76 32 5 23 (178) 467 - - - Depreciation (218) - (113) (83) (32) (4) (12) - (462) 9 (161) (614) Unrealized financial instrument loss 1 - - 2 - - (1) (15) (13) 1 3 (9) Deferred income tax recovery 36 - 4 16 2 - - 20 78 - 2 80 Other 14 - (8) (30) (1) - (4) (39) (68) - - (68) Share of earnings from equity accounted investments - - - - - - - - - (10) - (10) Net income attributable to non-controlling interests - - - - - - - - - - 156 156 Net income (loss) attributable to Unitholders (2) 206 - 19 (19) 1 1 6 (212) 2 - - 2
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 Corporate Total equity to non- Total North North Storage and accounted controlling (MILLIONS) America Colombia Brazil America Europe Brazil Other Other investments interests As at December 31, 2017: Property, plant and equipment, at fair value $ 11,396 $ 1,303 $ 1,908 $ 1,798 $ 482 $ 304 $ 11 $ 1,227 $ - $ 18,429 $ (1,451) $ 10,118 $ 27,096 Total assets 11,709 1,574 2,149 1,888 532 443 31 1,456 180 19,962 (1,040) 11,982 30,904 Total borrowings 3,049 447 200 1,005 233 192 9 752 2,552 8,439 (848) 4,175 11,766 Total liabilities 5,237 801 380 1,338 334 208 18 877 2,786 11,979 (1,039) 5,682 16,622 For the year ended December 31, 2017: Additions to property, plant and equipment 90 8 59 6 34 - - 13 10 220 (10) 144 354 As at December 31, 2016: Property, plant and equipment, at fair value $ 10,922 $ 1,273 $ 1,895 $ 1,327 $ 545 $ 139 $ - $ 491 $ - 16,592 $ (428) $ 9,093 $ 25,257 Total assets 11,219 1,577 2,059 1,389 587 153 - 561 182 17,727 (280) 10,290 27,737 Total borrowings 2,946 467 194 727 249 50 - 215 2,229 7,077 (232) 3,337 10,182 Total liabilities 5,414 824 340 990 337 51 - 268 2,418 10,642 (280) 4,703 15,065 For the year ended December 31, 2016: Additions to property, plant and equipment 86 9 79 3 18 1 - 18 8 222 (10) 146 358
The following table presents consolidated revenue split by geographical region:	(MILLIONS) 2017 2016 2015 United States $ 871 $ 786 $ 799 Colombia 797 819 - Canada 480 442 426 Brazil 366 269 265 Europe 111 136 138 2,625 2,452 1,628
The following table presents consolidated property, plant and equipment and equity-accounted investments split by geographical region:	(MILLIONS) 2017 2016 United States $ 11,131 $ 10,163 Colombia 5,401 5,275 Canada 5,810 5,845 Brazil 3,479 2,922 Europe 1,332 1,258 Other 664 - 27,817 25,463

OTHER INCOME (Tables)

OTHER INCOME (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Brookfield Renewables other income for the year ended December 31 is comprised of the following:	(MILLIONS) 2017 2016 2015 Interest income and other $ 32 $ 41 $ 21 Gain on available for sale investments (Note 3) 15 - - Gains on settlement of foreign currency contracts - 23 31 Gain on disposal (1) - - 53 Compensation related to expired Brazilian concession agreements (2) - - 17 $ 47 $ 64 $ 122 In 2015, the sale of the 102 MW wind facility in California resulted in a gain of $53 million. Brookfield Renewable’s share of the gain was $ 12 million, representing the 22 % interest in the facility, and is net of the cash portion of non-controlling interests. In 2015, concession agreements relating to two Brazilian hydroelectric facilities expired. Brookfield Renewable elected not to renew these agreements in exchange for compensation of $17 million.

DIRECT OPERATING COSTS (Tables)

DIRECT OPERATING COSTS (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Brookfield Renewables direct operating costs for the year ended December 31 are comprised of the following:	(MILLIONS) Notes 2017 2016 2015 Operations, maintenance and administration $ 567 $ 553 $ 396 Water royalties, property taxes and other 161 149 119 Fuel and power purchases (1) 226 313 15 Energy marketing fees 27 24 23 22 $ 978 $ 1,038 $ 552 F uel and power purchase s are primarily attributable to our portfolio in Colombia.

OTHER (Tables)

OTHER (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Brookfield Renewables other for the year ended December 31 is comprised of the following:	(MILLIONS) Notes 2017 2016 2015 Transaction costs $ (9) $ (22) $ (6) Change in fair value of property, plant and equipment 12 (33) (36) (45) Unrealized loss on available-for-sale securities - - (25) Other 14 20 13 $ (28) $ (38) $ (63)

FOREIGN CURRENCY TRANSLATION (T

FOREIGN CURRENCY TRANSLATION (Tables)	12 Months Ended
	Dec. 31, 2017
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 2017 2016 2015 Foreign currency translation on Property, plant and equipment, at fair value 12 $ 506 $ 1,186 $ (1,975) Long-term debt and credit facilities (282) (244) 697 Deferred income tax liabilities and assets (82) (157) 202 Other assets and liabilities 48 201 (62) $ 190 $ 986 $ (1,138)

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
The major components of income tax recovery (expense) for the year ended December 31 are as follows:	(MILLIONS) 2017 2016 2015 Income tax (expense) recovery applicable to: Current taxes Attributed to the current period $ (39) $ (44) $ (18) Deferred taxes Income taxes - origination and reversal of temporary differences $ 8 $ 71 $ 87 Relating to change in tax rates / imposition of new tax laws (42) 35 6 Relating to unrecognized temporary differences and tax losses (15) (9) (15) $ (49) $ 97 $ 78 Total income tax (expense) recovery $ (88) $ 53 $ 60
The major components of deferred income tax recovery (expense) for the year ended December 31 recorded directly to OCI are as follows:	(MILLIONS) 2017 2016 2015 Deferred income taxes attributed to: Financial instruments designated as cash flow hedges $ (4) $ 2 $ 8 Other 15 (7) (17) Revaluation surplus Origination and reversal of temporary differences (248) (55) (263) Relating to changes in tax rates / imposition of new tax laws 586 19 (19) $ 349 $ (41) $ (291)
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) 2017 2016 2015 Statutory income tax (expense) recovery (1) $ (50) $ 5 $ (15) (Reduction) increase resulting from: Increase in tax assets not recognized (15) (9) (15) Deemed profit method differences in Brazil 1 (11) 10 Differences between statutory rate and future tax rate (38) 54 68 Income or losses recorded not taxable to Brookfield Renewable 14 14 14 Other - - (2) Effective income tax (expense) recovery $ (88) $ 53 $ 60 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) 2017 2016 2018 to 2022 $ 8 $ - 2023 and thereafter 108 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:	Amount available Difference Net deferred Non-capital for future between tax and tax (liabilities) (MILLIONS) losses deductions carrying value assets As at January 1, 2015 $ 403 $ 88 $ (2,986) $ (2,495) Recognized in Net income (loss) 73 (11) 16 78 Recognized in equity (1) - (279) (280) Business combination 5 - (35) (30) Foreign exchange (22) (12) 223 189 As at December 31, 2015 458 65 (3,061) (2,538) Recognized in Net income (loss) 24 (10) 83 97 Recognized in equity 17 - (48) (31) Business combination - - (1,020) (1,020) Foreign exchange - 1 (161) (160) As at December 31, 2016 499 56 (4,207) (3,652) Recognized in Net income (loss) (97) (5) 53 (49) Recognized in equity 13 - 341 354 Business combination 79 - (63) 16 Foreign exchange 14 4 (98) (80) As at December 31, 2017 $ 508 $ 55 $ (3,974) $ (3,411)

PROPERTY, PLANT AND EQUIPMENT49

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
The following table presents a reconciliation of property, plant and equipment at fair value:	Solar and (MILLIONS) Notes Hydroelectric Wind Other (1) Total (2) As at December 31, 2014 $ 15,210 $ 3,315 $ 41 $ 18,566 Additions 183 51 55 289 Acquisitions through business combinations 3 307 624 229 1,160 Disposal - (230) - (230) Items recognized through OCI Change in fair value 1,141 52 16 1,209 Foreign exchange (1,585) (336) (54) (1,975) Items recognized through net income Change in fair value (2) (43) - (45) Depreciation (407) (200) (9) (616) 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 - 618 627 1,245 Disposal 4 - (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 $ 3,751 $ 946 $ 27,096 Includes solar, storage, biomass and Co-gen. Includes intangible assets of $ 13 million (201 6 : $ 1 4 million and 2015: $ 13 million ) and construction work in process (“CWIP”) of $ 601 million (201 6 : $ 663 million and 2015: $ 405 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 2017 2016 2017 2016 2017 2016 2017 2016 Discount rate Contracted 4.9% - 6.0% 4.8% - 5.5% 11.3% N/A 8.9% 9.2% 4.1% - 4.5% 4.1% - 5.0% Uncontracted 6.5% - 7.6% 6.6% - 7.2% 12.6% N/A 10.2% 10.5% 5.9% - 6.3% 5.9% - 6.8% Terminal capitalization rate (1) 6.2% - 7.5% 6.3% - 6.9% 0.126 N/A N/A N/A NA N/A Exit date 2037 2036 2037 N/A 2032 2031 2031 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:	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) (50) - - (230) 25 bps decrease in terminal capitalization rate (1) 190 50 - - 240 2016 North (MILLIONS) America Colombia Brazil Europe Total 25 bps increase in discount rates $ (670) $ N/A $ (50) $ (20) $ (740) 25 bps decrease in discount rates 730 N/A 50 20 800 5% increase in future electricity prices 540 N/A 70 20 630 5% decrease in future electricity prices (540) N/A (70) (20) (630) 25 bps increase in terminal capitalization rate (1) (180) N/A - - (180) 25 bps decrease in terminal capitalization rate (1) 190 N/A - - 190 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 58% 17% 66% 78% 11 - 20 years 42% - 57% 35% Per MWh (1) North America Colombia Brazil Europe 1 - 10 years $ 84 COP 211,000 R$ 274 € 90 11 - 20 years 88 - 407 107 Assumes nominal prices based on weighted-average generation. Per MWh (1) North America Colombia Brazil Europe 1 - 10 years $ 63 COP 238,000 R$ 309 € 78 11 - 20 years 112 339,000 458 95 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) 2017 2016 Hydroelectric $ 12,740 $ 12,761 Wind 3,030 2,688 Solar and other (1) 933 319 $ 16,703 $ 15,768 Includes biomass and Co-gen.

LONG-TERM DEBT AND CREDIT FAC50

LONG-TERM DEBT AND CREDIT FACILITIES (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
The composition of debt obligations as at December 31 is presented in the following table:	2017 2016 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 Corporate borrowings Series 3 (C$200) 5.3 0.8 $ 159 $ 163 5.3 1.8 $ 149 $ 158 Series 4 (C$150) 5.8 18.9 119 144 5.8 19.9 111 132 Series 7 (C$450) 5.1 2.8 358 382 5.1 3.8 334 368 Series 8 (C$400) 4.8 4.1 318 344 4.8 5.1 298 331 Series 9 (C$400) 3.8 7.4 318 321 3.8 8.4 298 308 Series 10 (C$500) 3.6 9.0 398 400 3.6 10.0 372 380 4.5 6.4 $ 1,670 $ 1,754 4.5 7.4 $ 1,562 $ 1,677 Credit facilities 2.6 4.5 $ 887 $ 887 1.9 4.5 $ 673 $ 673 Subsidiary borrowings Hydroelectric 6.3 8.8 $ 6,392 6,813 6.9 7.8 $ 6,249 6,600 Wind 5.8 9.7 2,211 2,343 4.6 13.1 1,735 1,879 Solar and other 11.0 8.2 682 682 8.9 18.8 41 41 6.5 9.0 $ 9,285 $ 9,838 6.4 9.0 $ 8,025 $ 8,520 Total debt 11,842 12,479 10,260 10,870 Add: Unamortized premiums (1) 1 2 Less: Unamortized financing fees (1) (77) (80) Less: Current portion (2)(3) (1,676) (1,034) $ 10,090 $ 9,148
The following table outlines changes in Brookfield Renewables borrowings for the year ended December 31:	Cash flows from Non-cash (MILLIONS) Jan 1 financing activities Acquisition Disposal Other (1) Dec 31 2017 $ 10,182 $ 267 $ 1,188 $ (173) $ 302 $ 11,766 2016 $ 7,338 $ 1,502 $ 1,104 $ - $ 238 $ 10,182
Future repayments of Brookfield Renewables debt obligations, for each of the next five years and thereafter are as follows:	(MILLIONS) 2018 2019 2020 2021 2022 Thereafter Total Corporate borrowings and credit facilities $ 159 $ 202 $ 377 $ - $ 984 $ 835 $ 2,557 Subsidiary borrowings Hydro 206 366 1,013 822 317 3,668 6,392 Wind 665 115 122 125 132 1,052 2,211 Solar and other 646 3 3 2 4 24 682 $ 1,676 $ 686 $ 1,515 $ 949 $ 1,437 $ 5,579 11,842 Equity-accounted investments $ 110 $ 116 $ 112 $ 716 $ 602 $ 3,003 $ 4,659 $ 16,501
The following table outlines change in financing fees for the year ended December 31:	(MILLIONS) 2017 2016 2015 Corporate borrowings Unamortized financing fees, beginning of year $ 6 $ 5 $ 5 Additional financing fees - 2 1 Amortization of financing fees (1) (1) (1) Unamortized financing fees, end of year $ 5 $ 6 $ 5 Subsidiary borrowings Unamortized financing fees, beginning of year $ 74 $ 54 $ 66 Additional financing fees 16 41 7 Amortization of financing fees (14) (17) (15) Foreign exchange translation and other (4) (4) (4) Unamortized financing fees, end of year $ 72 $ 74 $ 54 Total $ 77 $ 80 $ 59
The following table summarizes the available portion of credit facilities as at December 31:	(MILLIONS) 2017 2016 Authorized credit facilities $ 2,090 $ 1,890 Draws on credit facilities (1) (685) (673) Issued letters of credit (193) (250) Available portion of credit facilities $ 1,212 $ 967

NON-CONTROLLING INTERESTS (Tabl

NON-CONTROLLING INTERESTS (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Brookfield Renewables non-controlling interests are comprised of the following as at December 31:	(MILLIONS) 2017 2016 Participating non-controlling interests - in operating subsidiaries $ 6,298 $ 5,589 General partnership interest in a holding subsidiary held by Brookfield 58 55 Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield 2,843 2,680 Preferred equity 616 576 $ 9,815 $ 8,900
The net change in participating non-controlling interests in operating entities is as follows:	Isagen Brookfield Isagen public Americas Brookfield Brookfield The institu- non-con Infrastructure Infrastructure Infrastructure Catalyst tional -trolling (MILLIONS) Fund Fund II Fund III Group investors interests Other Total As at December 31, 2014 $ 914 $ 937 $ - $ 126 $ - $ - $ 85 $ 2,062 Net income 26 27 - 14 - - 2 69 OCI 89 144 - (12) - - (17) 204 Capital contributions - 460 - - - - - 460 Distributions (70) (126) - (7) - - (5) (208) Other (1) (1) - - - - 2 - As at December 31, 2015 $ 958 $ 1,441 $ - $ 121 $ - $ - $ 67 $ 2,587 Net (loss) 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 Interests held by third parties 75-80% 50-60% 23-71% 25% 53% 0.5% 21-50%
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 Infrastructure Infrastructure Infrastructure The Catalyst (MILLIONS) Fund Fund II Fund III (1) Group Isagen (2) Other Total Interests held by third parties 75-80% 50-60% 69-71% 25% 76% 21-50% Place of business United States, Brazil United States, Brazil, Europe United States, Brazil, India, China, South Africa United States Colombia United States, Brazil, Canada For the year ended December 31, 2015: Revenue $ 136 $ 402 $ - $ 160 $ - $ 30 $ 728 Net income 34 49 - 56 - 8 147 Total comprehensive income (loss) 144 247 - 8 - (51) 348 Net income allocated to non-controlling interests 26 27 - 14 - 2 69 For the year ended December 31, 2016: Revenue $ 118 $ 394 $ 28 $ 164 $ 819 $ 27 $ 1,550 Net (loss) income (22) (23) (8) 62 110 5 124 Total comprehensive income (loss) 37 356 (8) 70 502 31 988 Net (loss) income allocated to non-controlling interests (18) (16) (5) 16 86 2 65 As at December 31, 2016: Property, plant and equipment, at fair value $ 1,807 $ 4,816 $ 848 $ 970 $ 5,275 $ 417 $ 14,133 Total assets 1,865 5,125 855 1,072 6,539 428 15,884 Total borrowings 571 1,881 313 450 1,924 41 5,180 Total liabilities 631 2,235 319 466 3,396 60 7,107 Carrying value of non- controlling interests $ 963 $ 1,654 $ 383 $ 127 $ 2,391 $ 71 $ 5,589 For the 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 (loss) income (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 Excludes information relating to Isagen which is presented separately. The total third parties ownership interest in Isagen as of December 31, 2017 was 75.9 % and comprised of Brookfield Infrastructure Fund III: 22.9 %, Isagen Institutional investors 52.5 % and Isagen public non-controlling interests: 0.5 % .
The composition of the distributions for the year ended December 31 is presented in the following table:	(MILLIONS) 2017 2016 General partnership interest in a holding subsidiary held by Brookfield $ 5 $ 5 Incentive distribution 30 19 $ 35 $ 24 Participating non-controlling interests - in a holding subsidiary - Redeemable/ Exchangeable units held by Brookfield $ 243 $ 232 $ 278 $ 256
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) 2017 2016 2015 For the year ended December 31 : Revenue $ 2,625 $ 2,452 $ 1,628 Net income 51 40 103 Comprehensive income 1,401 1,369 5 Net income allocated to (1) : GP interest (1) - - Redeemable/Exchangeable partnership units (23) (29) 1 As at December 31 : Property, plant and equipment, at fair value $ 27,096 $ 25,257 Total assets 30,904 27,737 Total borrowings 11,766 10,182 Total liabilities 16,622 15,065 Carrying value of (2) : GP interest 58 55 Redeemable/Exchangeable partnership units 2,843 2,680 Allocated based on weighted-average GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 173.5 million, respectively ( 2016 : 2.7 million, 129.7 million, and 1 56.4 million, respectively and 2015 : 2.7 million, 129.7 million, and 143.3 million, respectively). Allocated based on outstanding GP interest, Redeemable/Exchangeable partnership units and LP Units of 2.7 million, 129.7 million, and 180.4 million, respectively ( 2016 : 2.7 million, 129.7 million, and 166.8 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 Cumulative permitted for the year ended (MILLIONS EXCEPT Shares dividend redemption December 31 AS NOTED) outstanding rate (%) date 2017 2016 2017 2016 Series 1 (C$136) 5.45 3.36 Apr 30, 2020 $ 4 $ 3 $ 108 $ 101 Series 2 (C$113) (1) 4.51 3.63 Apr 30, 2020 3 3 90 84 Series 3 (C$249) 9.96 4.40 Jul 31, 2019 8 8 197 185 Series 5 (C$103) 4.11 5.00 Apr 30, 2018 4 4 82 76 Series 6 (C$175) 7.00 5.00 Jul 31, 2018 7 7 139 130 31.03 $ 26 $ 25 $ 616 $ 576 Dividend rate represents annualized distribution based on the most recent quarterly floating rate .

PREFERRED LIMITED PARTNERS EQ52

PREFERRED LIMITED PARTNERS EQUITY (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Disclsoure of preferred limited partners equity [text block]	Earliest Distributions declared Cumulative permitted for the year ended (MILLIONS EXCEPT Shares distribution redemption December 31 AS NOTED) outstanding rate (%) date 2017 2016 2017 2016 Series 5 (C$72) 2.89 5.59 Apr 30, 2018 $ 4 $ 3 $ 49 $ 49 Series 7 (C$175) 7.00 5.50 Jan 31, 2021 8 7 128 128 Series 9 (C$200) 8.00 5.75 Jul 31, 2021 8 5 147 147 Series 11 (C$250) 10.00 5.00 Apr 30, 2022 8 - 187 - 27.89 $ 28 $ 15 $ 511 $ 324

LIMITED PARTNERS EQUITY (Tables

LIMITED PARTNERS EQUITY (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
The composition of the distributions for the year ended December 31 is presented in the following table:	(MILLIONS) 2017 2016 General partnership interest in a holding subsidiary held by Brookfield $ 5 $ 5 Incentive distribution 30 19 $ 35 $ 24 Participating non-controlling interests - in a holding subsidiary - Redeemable/ Exchangeable units held by Brookfield $ 243 $ 232 $ 278 $ 256

GOODWILL (Tables)

GOODWILL (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
The following table provides a reconciliation of goodwill:	(MILLIONS) 2017 2016 Balance, beginning of year $ 896 $ - Acquired through business acquisition - 799 Foreign exchange 5 97 Balance, end of year $ 901 $ 896

CAPITAL MANAGEMENT (Tables)

CAPITAL MANAGEMENT (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Brookfield Renewables strategy during December 31, 2016, which was unchanged from 2015, was to maintain the measure set out in the following schedule as at December 31:	(MILLIONS) 2017 2016 Total debt Current portion of long-term debt (1) $ 1,676 $ 1,034 Long-term debt and credit facilities 10,090 9,148 11,766 10,182 Deferred income tax liabilities, net (2) 3,411 3,652 Equity 14,282 12,672 Total capitalization $ 29,459 $ 26,506 Debt to total capitalization 40% 38% As part of the TerraForm Global transaction, Brookfield Renewable acquired $ 841 million of borrowings that were immediately classified as current due to the change of control provision allowing the holders to direct TerraForm Global to redeem the bonds at 101 % of par value in the first quarter of 2018. Brookfield Renewable redeemed these borrowings at approximately 107 % of par value in the first quarter of 2018 with a combination of available cash on hand and proceeds from note offering th at closed on February 22, 2018. See Note 20 – Cash and Cash Equivalents and Note 31 – Subsequent Events Deferred income tax liabilities less deferred income tax assets.

EQUITY-ACCOUNTED INVESTMENTS (T

EQUITY-ACCOUNTED INVESTMENTS (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
The following are Brookfield Renewables equity-accounted investments as at December 31:	Principal place Ownership Carrying value of business interest (MILLIONS) % 2017 2016 FHH (Guernsey) Limited Europe 25 $ 245 $ - TerraForm Power Inc. (1) United States, Canada 16 212 - Bear Swamp Power Co. L.L.C. United States 50 173 114 Galera Centrais Eletricas S.A. Brazil 50 28 29 Pingston Power Inc. Canada 50 57 58 Brookfield Infrastructure Fund II Investees United States, Europe 14 - 50 6 5 $ 721 $ 206
The following table outlines the changes in Brookfield Renewables equity-accounted investments for the year ended December 31:	(MILLIONS) 2017 2016 2015 Balance, beginning of year $ 206 $ 197 $ 273 Share of net income 2 - 10 Share of OCI Revaluation of property, plant and equipment 54 7 96 Other 2 1 - Dividends declared (31) (6) (19) Capital distributions, net - - (144) Acquisition of European Storage (Note 3) 248 - - Acquisition of TerraForm Power (Note 3) 221 - - Foreign exchange translation 19 7 (19) Balance, end of year $ 721 $ 206 $ 197
The following tables summarize certain financial information of equity-accounted investments:	(MILLIONS) 2017 2016 As at December 31: Current assets $ 477 $ 45 Property, plant and equipment, at fair value 8,098 864 Other assets 213 70 Current liabilities 687 42 Long-term debt 4,294 463 Other liabilities 958 71 (MILLIONS) 2017 2016 2015 For the year ended December 31 Revenue $ 310 $ 74 $ 89 Net (loss) income (24) - 19 Share of net income (loss) Cash earnings 29 9 20 Non-cash loss (27) (9) (10)

CASH AND CASH EQUIVALENTS (Tabl

CASH AND CASH EQUIVALENTS (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Brookfield Renewables cash and cash equivalents as at December 31 are as follows:	(MILLIONS) 2017 2016 Cash (1) $ 790 $ 210 Short-term deposits 9 13 $ 799 $ 223

COMMITMENTS, CONTINGENCIES AN58

COMMITMENTS, CONTINGENCIES AND GUARANTEES (Tables)	12 Months Ended
	Dec. 31, 2017
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) 2018 $ 33 2019 32 2020 31 2021 30 2022 27 Thereafter 262 Total $ 415
As at December 31, letters of credit issued by Brookfield Renewable along with institutional investors and its subsidiaries were as follows:	(MILLIONS) 2017 2016 Brookfield Renewable along with institutional investors $ 76 $ 66 Brookfield Renewable's subsidiaries 468 483 $ 544 $ 549

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2017
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) 2017 2016 2015 Revenues Power purchase and revenue agreements $ 601 $ 527 $ 469 Wind levelization agreement 6 8 6 $ 607 $ 535 $ 475 Direct operating costs Energy purchases $ (13) $ (3) $ (5) Energy marketing fee (24) (23) (22) Insurance services (19) (20) (30) $ (56) $ (46) $ (57) Management service costs $ (82) $ (62) $ (48)

SUPPLEMENTAL INFORMATION (Table

SUPPLEMENTAL INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2017
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) 2017 2016 2015 Trade receivables and other current assets $ (40) $ 30 $ (72) Accounts payable and accrued liabilities 32 (160) 2 Other assets and liabilities (17) (7) 8 $ (25) $ (137) $ (62)

PENSION AND EMPLOYEE FUTURE B61

PENSION AND EMPLOYEE FUTURE BENEFITS (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
Actuarial assumptions as at December 31:	Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans 2017 2016 2015 (%) (%) (%) Discount rate 2.4 - 7.3 3.7 - 7.1 2.2 - 7.3 4.1 - 7.3 2.9 - 4.7 4.2 - 4.7 Rate of price inflation 1.5 - 3.5 N/A 1.5 - 3.5 N/A 2.0 - 2.5 N/A Rate of compensation increases 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 4.0 2.5 - 3.0 2.5 - 3.0 Health care trend rate (1) N/A 5.3 - 6.9 N/A 5.3 - 6.9 N/A 6.3 - 7.1
Expense recognized in the consolidated statements of income and consolidated statements of comprehensive income for the year ended December 31:	Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Current service costs $ 3 $ 1 $ 3 $ 1 $ 3 $ 1 Past service costs (recovery) (1) - - - 1 (1) Interest expense 2 3 2 3 1 2 Administrative expenses 1 - 1 - 1 - Recognized in consolidated statement of income 5 4 6 4 6 2 Remeasurement of the net defined benefit liability: Return on plan assets (8) - (2) - (1) - Actuarial changes arising from changes in demographic assumptions 1 (2) (1) (1) 2 (5) Actuarial changes arising from changes in financial assumptions 7 3 5 1 (2) (1) Experience adjustments - 1 - - 2 - Recognized in consolidated statement of comprehensive income - 2 2 - 1 (6) Total $ 5 $ 6 $ 8 $ 4 $ 7 $ (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:	Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Present value of defined benefit obligation $ 172 $ 57 $ 158 $ 53 $ 124 $ 35 Fair value of plan assets (135) (5) (119) (5) (103) - Net liability $ 37 $ 52 $ 39 $ 48 $ 21 $ 35 Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Balance, beginning of year $ 158 $ 53 $ 124 $ 35 $ 128 $ 43 Current service cost 3 1 3 1 3 1 Past service (recovery) cost (1) - - - 1 (1) Interest expense 7 3 7 3 5 2 Remeasurement losses (gains) Actuarial changes arising from changes in demographic assumptions 1 (2) (1) (1) 2 (5) Actuarial changes arising from changes in financial assumptions 7 3 5 1 (2) (1) Experience adjustments - 1 - - 2 - Benefits paid (7) (2) (8) (2) (5) (2) Business combination - - 25 14 - - Exchange differences 4 - 3 2 (10) (2) Balance, end of year $ 172 $ 57 $ 158 $ 53 $ 124 $ 35
The movement in the fair value of plan assets for the year ended December 31 is as follows:	Defined benefit Non-pension Defined benefit Non-pension Defined benefit Non-pension pension plans benefit plans pension plans benefit plans pension plans benefit plans (MILLIONS) 2017 2016 2015 Balance, beginning of year $ 119 $ 5 $ 103 $ - $ 108 $ - Interest income 5 - 5 - 4 - Return on plan assets 8 - 2 - 1 - Employer contributions 5 2 7 3 5 2 Business combination - - 9 4 - - Benefits paid (7) (2) (8) (2) (5) (2) Exchange differences 5 - 1 - (10) - Balance, end of year $ 135 $ 5 $ 119 $ 5 $ 103 $ -
The composition of plan assets as at December 31 is as follows:	2017 2016 (%) (%) Asset category: Cash and cash equivalents 2 5 Equity securities 54 50 Debt securities 44 44 Real estate - 1 100 100

SUBSIDIARY PUBLIC ISSUERS (Tabl

SUBSIDIARY PUBLIC ISSUERS (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Block [Abstract]
The following tables provide consolidated summary balance sheet 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 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 As at December 31, 2016: Current assets $ 26 $ - $ 1,581 $ 150 $ 2,092 $ (2,942) $ 907 Long-term assets 3,779 620 - 18,415 27,250 (23,234) 26,830 Current liabilities 33 9 19 2,971 1,644 (2,943) 1,733 Long-term liabilities - - 1,556 738 12,775 (1,737) 13,332 Participating non-controlling interests - in operating subsidiaries - - - - 5,589 - 5,589 Participating non-controlling interests -in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield - - - 2,680 - - 2,680 Preferred equity - 576 - - - - 576 Preferred limited partners' equity 324 - - 324 - (324) 324 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, 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 For the year ended December 31, 2015 Revenues $ - $ - $ - $ 8 $ 1,620 $ - $ 1,628 Net income (loss) 2 - (1) (42) 235 (91) 103 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.

PRINCIPAL SUBSIDIARIES (Details

PRINCIPAL SUBSIDIARIES (Details)	12 Months Ended
	Dec. 31, 2017
Alta Wind VIII LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
BIF II Safe Harbor Holdings LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
BIF III Holtwood LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
BRE GLBL Holdings L.P.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Bermuda
Percentage of voting securities owned or controlled	100.00%
BRI Green Energy Limited
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Republic of Ireland
Percentage of voting securities owned or controlled	100.00%
Brookfield BRP Canada Corp.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Alberta
Percentage of voting securities owned or controlled	100.00%
Brookfield Energia Comercializadora Ltda
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Brazil
Percentage of voting securities owned or controlled	100.00%
Brookfield Power US Holding America Co.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
Brookfield Power Wind Prince LP
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Ontario
Percentage of voting securities owned or controlled	100.00%
Brookfield Renewable UK Hydro Limited
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	England and Wales
Percentage of voting securities owned or controlled	100.00%
Brookfield Smoky Mountain Hydropower LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
Brookfield White Pine Hydro LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
Catalyst Old River Hydroelectric Limited Partnership
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Louisiana
Percentage of voting securities owned or controlled	75.00%
Erie Boulevard Hydropower, L.P.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
Granite Reliable Power, LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	89.50%
Great Lakes Hydro America, LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
Great Lakes Power Limited
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Ontario
Percentage of voting securities owned or controlled	100.00%
Hawks Nest Hydro LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
Isagen S.A. E.S.P.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Colombia
Percentage of voting securities owned or controlled	99.50%
Itiquira Energetica S.A.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Brazil
Percentage of voting securities owned or controlled	100.00%
Kwagis Power Limited Partnership
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	British Columbia
Percentage of voting securities owned or controlled	75.00%
Lievre Power L.P.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Québec
Percentage of voting securities owned or controlled	100.00%
Mississagi Power Trust
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Québec
Percentage of voting securities owned or controlled	100.00%
Orion Canadian Holdings 1 AIV L.P.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Ontario
Percentage of voting securities owned or controlled	100.00%
PEA - Parque Eolico da Serra, Unipessola S.A.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Portugal
Percentage of voting securities owned or controlled	100.00%
Powell River Energy Inc.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Canada
Percentage of voting securities owned or controlled	100.00%
Rumford Falls Hydro LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Delaware
Percentage of voting securities owned or controlled	100.00%
Safe Harbor Water Power Corporation
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Pennsylvania
Percentage of voting securities owned or controlled	100.00%
Tangara Energia S.A.
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Brazil - São Paulo
Percentage of voting securities owned or controlled	100.00%
Windstar Energy, LLC
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	California
Percentage of voting securities owned or controlled	100.00%
2016 Comber Wind Limited Partnership
Disclosure of subsidiaries [line items]
Jurisdiction of Incorporation or Organization	Ontario
Percentage of voting securities owned or controlled	100.00%

ACQUISITIONS (Details)

ACQUISITIONS (Details) € in Millions, £ in Millions, BRL in Millions, $ in Millions	Jan. 22, 2016GWh	Dec. 31, 2017USD ($)	Oct. 31, 2017USD ($)	Aug. 31, 2017GBP (£)	Aug. 31, 2017USD ($)	Feb. 28, 2017	Sep. 30, 2016USD ($)	Apr. 30, 2016USD ($)GWh	Jan. 31, 2016USD ($)	Jun. 30, 2015USD ($)MW	Feb. 28, 2015EUR (€)GWhMW	Nov. 30, 2014USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Aug. 31, 2017USD ($)	Sep. 30, 2016EUR (€)	Sep. 30, 2016USD ($)	Jan. 31, 2016BRL	Jan. 31, 2016USD ($)	Jun. 30, 2015GBP (£)	Jun. 30, 2015USD ($)	Feb. 28, 2015USD ($)	Nov. 30, 2014BRL	Nov. 30, 2014USD ($)
Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Gain (loss) on reclassification		$ 2	$ 13
Acquisition costs incurred and capitalized			$ 1
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 long-term debt		1,183
Financial instruments		15
Long-term debt		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
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
Brookfield Renewable | Acqusitions Completed In 2015
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents														$ 19
Restricted cash														21
Trade receivables and other current assets														20
Property, plant and equipment, at fair value														1,147
Current liabilities														41
Long-term debt														391
Other long-term liabilities														28
Non-controlling interests														16
Fair value of net assets acquired														731
FHH Guernsey Ltd | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree				FHH Guernsey Ltd	FHH Guernsey Ltd
Date of acquisition				August 2,017	August 2,017
Percentage of voting equity interests acquired				25.00%											25.00%
Percentage of voting equity interests Retained by Brookfield				7.00%											7.00%
Consideration transferred				£ 194											$ 248
Acquisition costs incurred and capitalized				£ 1	$ 1
TerraForm Power | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree			TerraForm Power
Date of acquisition			October 2,017
Percentage of voting equity interests acquired			51.00%
Percentage of voting equity interests Retained by Brookfield			16.00%
Consideration transferred			$ 203
European Wind | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree						European Wind
Date of acquisition						February 2,017
Percentage of voting equity interests acquired						100.00%
Percentage of voting equity interests Retained by Brookfield				40.00%											40.00%
Total cash consideration transferred				£ 24											$ 32
Acquisition costs incurred and capitalized					$ 1
European 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 long-term debt		0
Financial instruments		0
Long-term debt		0
Deferred income tax liabilities		2
Other long-term liabilities		0
Non-controlling interests		0
Fair value of net assets acquired		32
Terraform Global
Disclosure of detailed information about business combination [line items]
Consideration transferred		657
Fair Value of Interest Held at Acquisition Date		$ 100
Terraform Global | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree		TerraForm Global
Date of acquisition		December 2,017
Percentage of voting equity interests acquired		100.00%
Percentage of voting equity interests Retained by Brookfield		31.00%
Revenue of acquiree since acquisition date		$ 250
Consideration transferred		202
Fair Value of Interest Held at Acquisition Date		30
Acquisition costs incurred and capitalized		1
Terraform Global | 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		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 long-term debt		1,183
Financial instruments		15
Long-term debt		5
Deferred income tax liabilities		15
Other long-term liabilities		54
Non-controlling interests		1
Fair value of net assets acquired		$ 757
Colombia Portfolio | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Percentage of voting equity interests acquired		99.50%
Colombia 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													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
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
Disclosure of detailed information about business combination [line items]
Name of acquiree	Isagen S.A. E.S.P
Date of acquisition	January 22, 2016
Percentage of voting equity interests acquired	57.60%	99.50%
Percentage of voting equity interests Retained by Brookfield		24.00%
Revenue of acquiree since acquisition date													900
Annual generation Energy, GWh | GWh	15,000
Acquisition costs incurred and capitalized													13
Brazil portfolio
Disclosure of detailed information about business combination [line items]
Consideration transferred														588
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents														19
Restricted cash														16
Trade receivables and other current assets														16
Property, plant and equipment, at fair value														854
Current liabilities														(21)
Long-term debt														(280)
Other long-term liabilities														0
Non-controlling interests														(16)
Brazil portfolio | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Deferred consideration																		BRL 35	$ 9
Impact of the foreign currency contracts																		24	6
Brazil 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													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
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
Brazil portfolio | Brookfield Renewable | Acqusitions Completed In 2015
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents														19
Restricted cash														16
Trade receivables and other current assets														16
Property, plant and equipment, at fair value														854
Current liabilities														21
Long-term debt														280
Other long-term liabilities														0
Non-controlling interests														16
Fair value of net assets acquired														$ 588
51 MW hydroelectric portfolio | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree									51 MW hydroelectric
Date of acquisition									January 2,016
Total cash consideration transferred																		355	88
Consideration transferred																		BRL 417	$ 103
Acquisition costs incurred and capitalized									$ 1
488 MW portfolio | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree														488 MW portfolio
Date of acquisition														November 2,014
Percentage of voting equity interests Retained by Brookfield																							40.00%	40.00%
Total cash consideration transferred																							BRL 1,717	$ 541
Revenue of acquiree since acquisition date														$ 93
Consideration transferred																							1,867	588
Acquisition costs incurred and capitalized												$ 2
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Non-controlling interests																							BRL 50	$ 16
North America portfolio | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Acquisition costs incurred and capitalized								$ 6
Pennsylvania Hydro | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree								Pennsylvania Hydro
Date of acquisition								April 2,016
Percentage of voting equity interests Retained by Brookfield								28.60%
Total cash consideration transferred								$ 859
Revenue of acquiree since acquisition date													46
Annual generation Energy, GWh | GWh								1,109
Pennsylvania 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
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 Portfolio | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Acquisition costs incurred and capitalized							$ 1
Ireland 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													0
Property, plant and equipment, at fair value													10
Other long-term assets													0
Current liabilities													0
Long-term debt													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
19 MW wind development project | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree							19 MW wind development project
Date of acquisition							September 2,016
Percentage of voting equity interests Retained by Brookfield																40.00%	40.00%
Total cash consideration transferred																€ 7	$ 8
Deferred consideration																1	1
Consideration transferred																€ 8	$ 9
Portugal Wind Portfolio | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree											Portugal Wind Portfolio
Date of acquisition											February 2,015
Percentage of voting equity interests Retained by Brookfield											40.00%											40.00%
Total cash consideration transferred											€ 58											$ 63
Revenue of acquiree since acquisition date														28
Annual generation Energy, GWh | GWh											260
Aggregate Capacity, MW | MW											123
Consideration transferred											€ 65											$ 71
Scotland Wind Pipeline | Brookfield Renewable
Disclosure of detailed information about business combination [line items]
Name of acquiree										Scotland Wind Pipeline
Date of acquisition										June 2,015
Total cash consideration transferred																				£ 40	$ 62
Deferred consideration																				6	9
Aggregate Capacity, MW | MW										1,200
Consideration transferred																				47	72
Acquisition costs incurred and capitalized										$ 1
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Other long-term liabilities																				£ 63	$ 97
Portugal Portfolio
Disclosure of detailed information about business combination [line items]
Consideration transferred														71
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents														0
Restricted cash														5
Trade receivables and other current assets														3
Property, plant and equipment, at fair value														209
Current liabilities														(19)
Long-term debt														(111)
Other long-term liabilities														(16)
Non-controlling interests														0
Portugal Portfolio | Brookfield Renewable | Acqusitions Completed In 2015
Amounts recognised as of acquisition date for each major class of assets acquired and liabilities assumed [abstract]
Cash and cash equivalents														0
Restricted cash														5
Trade receivables and other current assets														3
Property, plant and equipment, at fair value														209
Current liabilities														19
Long-term debt														111
Other long-term liabilities														16
Non-controlling interests														0
Fair value of net assets acquired														71
Scotland Portfolio
Disclosure of detailed information about business combination [line items]
Consideration transferred														72
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														84
Current liabilities														(1)
Long-term debt														0
Other long-term liabilities														(12)
Non-controlling interests														0
Scotland Portfolio | Brookfield Renewable | Acqusitions Completed In 2015
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														84
Current liabilities														1
Long-term debt														0
Other long-term liabilities														12
Non-controlling interests														0
Fair value of net assets acquired														$ 72

RISK MANAGEMENT AND FINANCIAL65

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Sensitivity analysis) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount	$ 11,842	$ 10,260
Subsidiaries [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount	9,285	8,025
Interest rate risk | Subsidiaries [member] | Floating interest rate [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount	4,176	4,194
Hedged item, liabilities	824	966
Interest rate risk | Impact Of One Percent Increase | Floating interest rate [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	17	(17)	$ (15)
Effect on other comprehensive income	54	115	125
Interest rate risk | Impact Of One Percent decrease | Floating interest rate [member]
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	(17)	17	15
Effect on other comprehensive income	(54)	(115)	(125)
Currency risk | Impact Of Five Percent Increase
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	4	1	2
Effect on other comprehensive income	79	51	10
Currency risk | Impact Of Five Percent Decrease
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	(4)	(1)	(2)
Effect on other comprehensive income	(79)	(51)	(10)
Commodity price risk | Impact Of Five Percent Increase
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	(3)	(1)	(2)
Effect on other comprehensive income	4	(7)	(7)
Commodity price risk | Impact Of Five Percent Decrease
Disclosure of risk management strategy related to hedge accounting [line items]
Effect on profit loss	3	1	2
Effect on other comprehensive income	$ 4	$ 7	$ 7

RISK MANAGEMENT AND FINANCIAL66

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Credit risk) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure Of Credit Risk Exposure [Line Items]
Cash and cash equivalents	$ 799	$ 223	$ 63	$ 150
Restricted cash	284	250
Trade and other current receivables excluding prepaid	442	365
Financial instrument assets	185	200
Due from related parties	60	54
Total	$ 1,770	$ 1,092

RISK MANAGEMENT AND FINANCIAL67

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Cash obligations) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Accounts payable and accrued liabilities	$ 542	$ 467
Financial instrument liabilities	270	228
Due to related parties	112	76
Other long-term liabilities - concession payments	344	310
Long-term debt and credit facilities	11,842	10,260
Interest payable on long-term debt	4,255	3,859
Cash obligations	17,035	14,906
Concession Payments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Other long-term liabilities - concession payments	14	16
Less than 1 Year
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Accounts payable and accrued liabilities	542	467
Financial instrument liabilities	184	156
Due to related parties	112	76
Long-term debt and credit facilities	1,676	1,034
Interest payable on long-term debt	634	589
Cash obligations	3,149	2,323
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]
Financial instrument liabilities	62	66
Due to related parties		0
Long-term debt and credit facilities	4,587	3,970
Interest payable on long-term debt	1,924	1,821
Cash obligations	6,576	5,861
Between 2-5 years | Concession Payments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Other long-term liabilities - concession payments	3	4
Greater than 5 years
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Financial instrument liabilities	24	6
Due to related parties		0
Long-term debt and credit facilities	5,579	5,256
Interest payable on long-term debt	1,697	1,449
Cash obligations	7,310	6,722
Greater than 5 years | Concession Payments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Other long-term liabilities - concession payments	$ 10	$ 11

RISK MANAGEMENT AND FINANCIAL68

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Classes of assets and liabilities table) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure of classification of assets liabilities [line items]
Cash and cash equivalents	$ 799	$ 223	$ 63	$ 150
Restricted cash	181	121
Trade and other receivables excluding prepaid	442	365
Other Current Assets	112	89
Due from related parties	60	54
Financial instrument assets	185	200
Equity-accounted investments	721	206	197	273
Property, plant and equipment, at fair value	27,096	25,257	18,358	$ 18,566
Goodwill	901	896
Deferred income tax assets	177	150
Other long-term assets	230	176
Total assets	30,904	27,737
Accounts payable and accrued liabilities	542	467
Financial instrument liabilities	270	228
Due to related parties	112	76
Borrowings	11,766	10,182	$ 7,338
Deferred income tax liabilities	3,588	3,802
Other long-term liabilities	344	310
Total liabilities	16,622	15,065
Cash, loans and receivables
Disclosure of classification of assets liabilities [line items]
Cash and cash equivalents	799	223
Restricted cash	181	121
Trade and other receivables excluding prepaid	442	365
Other Current Assets	0	0
Due from related parties	60	54
Financial instrument assets	0	0
Equity-accounted investments	0	0
Property, plant and equipment, at fair value	0	0
Goodwill	0	0
Deferred income tax assets	0	0
Other long-term assets	103	129
Total assets	1,585	892
Accounts payable and accrued liabilities	0	0
Financial instrument liabilities	0	0
Due to related parties	0	0
Borrowings	0	0
Deferred income tax liabilities	0	0
Other long-term liabilities	0	0
Total liabilities	0	0
Assets/liabilities
Disclosure of classification of assets liabilities [line items]
Cash and cash equivalents	0	0
Restricted cash	0	0
Trade and other receivables excluding prepaid	0	0
Other Current Assets	0	0
Due from related parties	0	0
Financial instrument assets	20	14
Equity-accounted investments	0	0
Property, plant and equipment, at fair value	0	0
Goodwill	0	0
Deferred income tax assets	0	0
Other long-term assets	0	0
Total assets	20	14
Accounts payable and accrued liabilities	0	0
Financial instrument liabilities	145	11
Due to related parties	0	0
Borrowings	0	0
Deferred income tax liabilities	0	0
Other long-term liabilities	0	0
Total liabilities	145	11
Derivatives used for hedging
Disclosure of classification of assets liabilities [line items]
Cash and cash equivalents	0	0
Restricted cash	0	0
Trade and other receivables excluding prepaid	0	0
Other Current Assets	0	0
Due from related parties	0	0
Financial instrument assets	6	50
Equity-accounted investments	0	0
Property, plant and equipment, at fair value	0	0
Goodwill	0	0
Deferred income tax assets	0	0
Other long-term assets	0	0
Total assets	6	50
Accounts payable and accrued liabilities	0	0
Financial instrument liabilities	125	217
Due to related parties	0	0
Borrowings	0	0
Deferred income tax liabilities	0	0
Other long-term liabilities	0	0
Total liabilities	125	217
Other Financial Assets Liabilities
Disclosure of classification of assets liabilities [line items]
Cash and cash equivalents	0	0
Restricted cash	0	0
Trade and other receivables excluding prepaid	0	0
Other Current Assets	0	0
Due from related parties	0	0
Financial instrument assets	159	136
Equity-accounted investments	0	0
Property, plant and equipment, at fair value	0	0
Goodwill	0	0
Deferred income tax assets	0	0
Other long-term assets	0	0
Total assets	159	136
Accounts payable and accrued liabilities	542	467
Financial instrument liabilities	0	0
Due to related parties	112	76
Borrowings	11,766	10,182
Deferred income tax liabilities	0	0
Other long-term liabilities	344	310
Total liabilities	12,764	11,035
Nonfinancial assets and nonfinancial liabilities
Disclosure of classification of assets liabilities [line items]
Cash and cash equivalents	0	0
Restricted cash	0	0
Trade and other receivables excluding prepaid	0	0
Other Current Assets	112	89
Due from related parties	0	0
Financial instrument assets	0	0
Equity-accounted investments	721	206
Property, plant and equipment, at fair value	27,096	25,257
Goodwill	901	896
Deferred income tax assets	177	150
Other long-term assets	127	47
Total assets	29,134	26,645
Accounts payable and accrued liabilities	0	0
Financial instrument liabilities	0	0
Due to related parties	0	0
Borrowings	0	0
Deferred income tax liabilities	3,588	3,802
Other long-term liabilities	0	0
Total liabilities	$ 3,588	$ 3,802

RISK MANAGEMENT AND FINANCIAL69

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Fair value hierarchy) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure of financial assets [line items]
Cash and cash equivalents	$ 799	$ 223	$ 63	$ 150
Restricted Cash And Cash Equivalents	284	250
Financial instrument assets	185	200
Property, plant and equipment, at fair value	27,096	25,257	$ 18,358	$ 18,566
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	270	228
Contingent consideration	(18)	(16)
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	(12,479)	(10,870)
Level 1
Disclosure of financial assets [line items]
Cash and cash equivalents	799
Restricted Cash And Cash Equivalents	284
Property, plant and equipment, at fair value	0
Disclosure Of Financial Liabilities [Line items]
Contingent consideration	0
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	0
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
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	(12,479)
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	27,096
Disclosure Of Financial Liabilities [Line items]
Contingent consideration	(18)
Liabilties for which fair value is disclosed
Long-term debt and credit facilities	0
Energy Derivative Contracts
Disclosure of financial assets [line items]
Financial instrument assets	0	8
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(19)	(5)
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	0
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(19)
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	6	7
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(155)	(178)
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	6
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(155)
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	20	49
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(96)	(45)
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	20
Disclosure Of Financial Liabilities [Line items]
Financial instrument liabilities	(96)
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
Available-for-sale investments
Disclosure of financial assets [line items]
Financial instrument assets	159	$ 136
Available-for-sale investments | Level 1
Disclosure of financial assets [line items]
Financial instrument assets	79
Available-for-sale investments | Level 2
Disclosure of financial assets [line items]
Financial instrument assets	80
Available-for-sale investments | Level 3
Disclosure of financial assets [line items]
Financial instrument assets	$ 0

RISK MANAGEMENT AND FINANCIAL70

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Net position) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	$ 85	$ 28	$ 145	$ 77
Assets
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	185
Financial assets liabilities net position current portion	72
Financial assets liabilities net position noncurrent portion	113
Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	270
Financial assets liabilities net position current portion	184
Financial assets liabilities net position noncurrent portion	86
Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	85	28
Financial assets liabilities net position current portion	112	101
Financial assets liabilities net position noncurrent portion	(27)	(73)
Energy Derivative Contracts | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	0
Energy Derivative Contracts | Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	19
Energy Derivative Contracts | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	19	(3)
Interest Rate Swaps | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	6
Interest Rate Swaps | Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	155
Interest Rate Swaps | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	149	171
Foreign exchange swaps | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	20
Foreign exchange swaps | Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	96
Foreign exchange swaps | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	76	(4)
Available-for-sale investments | Assets
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	159
Available-for-sale investments | Net (Assets) Liabilities
Disclosure of derivative assets liabilities net position [Line Items]
Financial assets liabilities net position	$ (159)	$ (136)

RISK MANAGEMENT AND FINANCIAL71

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Continuity) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of derivative assets liabilities net position [Line Items]
Balance, beginning of year	$ 28	$ 145	$ 77
Unrealized financial instruments loss	33	4	9
Gain (loss) arising during the period on financial instruments designated as cash-flow hedges	4	8	10
Unrealized (loss) gain on foreign currency swaps - net investment hedge	(94)	(66)	55
Unrealized gain on available-for-sale securities	(22)	61	0
Acquisitions, settlements and other	(89)	(159)	68
Balance, end of year	85	28	145
Energy Derivative Contracts
Disclosure of derivative assets liabilities net position [Line Items]
Unrealized financial instruments loss	5	0	(2)
Gain (loss) arising during the period on financial instruments designated as cash-flow hedges	17	28	3
Interest Rate Swaps
Disclosure of derivative assets liabilities net position [Line Items]
Unrealized financial instruments loss	(1)	7	(2)
Gain (loss) arising during the period on financial instruments designated as cash-flow hedges	(18)	1	20
Foreign exchange swaps
Disclosure of derivative assets liabilities net position [Line Items]
Unrealized financial instruments loss	29	(3)	13
Gain (loss) arising during the period on financial instruments designated as cash-flow hedges	94	61	(57)
Available-for-sale investments
Disclosure of derivative assets liabilities net position [Line Items]
Unrealized financial instruments loss	0	0	25
Gain (loss) arising during the period on financial instruments designated as cash-flow hedges	20	(52)	0
Unrealized gain on available-for-sale securities	$ 20	$ (52)	$ 25

RISK MANAGEMENT AND FINANCIAL72

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Breakdown hedged not hedged) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	$ 270	$ 228
Financial instrument assets	185	200
Net Position	85	28	$ 145	$ 77
Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	145	11	0
Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	125	217	191
Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(179)	(150)	(15)
Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Net Position	(6)	(50)	(31)
Energy Derivative Contracts
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	(19)	(5)
Financial instrument assets	0	8
Energy Derivative Contracts | Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	5	3	0
Energy Derivative Contracts | Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	14	2	1
Energy Derivative Contracts | Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	0	(3)	0
Energy Derivative Contracts | Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	0	(5)	(31)
Interest Rate Swaps
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	(155)	(178)
Financial instrument assets	6	7
Interest Rate Swaps | Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	107	2	0
Interest Rate Swaps | Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	48	176	178
Interest Rate Swaps | Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	(1)	(1)	0
Interest Rate Swaps | Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	(5)	(6)	0
Foreign exchange swaps
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	(96)	(45)
Financial instrument assets	20	49
Foreign exchange swaps | Financial Instruments Liabilities Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	33	6	0
Foreign exchange swaps | Financial Instruments Liabilities Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument liabilities	63	39	12
Foreign exchange swaps | Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	(19)	(10)	(1)
Foreign exchange swaps | Financial Instruments Assets Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	(1)	(39)	0
Available-for-sale investments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	159	136
Available-for-sale investments | Financial Instruments Assets Not Designated As Hedging Instruments
Disclosure of financial assets and liabilities [line items]
Financial instrument assets	$ (159)	$ (136)	$ (14)

RISK MANAGEMENT AND FINANCIAL73

RISK MANAGEMENT AND FINANCIAL INSTRUMENTS (Details - Explanation) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of risk management strategy related to hedge accounting [line items]
Reclassification adjustments for amounts recognized in net (loss) income	$ (1)	$ (41)	$ (32)
Notional amount	11,842	10,260
Energy Derivative Contracts
Disclosure of risk management strategy related to hedge accounting [line items]
Reclassification adjustments for amounts recognized in net (loss) income	23	48	32
Gain (loss) expected to be reclassed in the next twelve months	9	6	25
Interest Rate Swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Reclassification adjustments for amounts recognized in net (loss) income	20	16	0
Gain (loss) expected to be reclassed in the next twelve months	18	110	114
Notional amount	1,704	2,397
Interest Rate Swaps | Not Designated as Hedging Instrument
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount	$ 780	$ 871
Derivative, Weighted Average Fixed interest rate	4.50%	2.50%
Foreign exchange swaps
Disclosure of risk management strategy related to hedge accounting [line items]
Reclassification adjustments for amounts recognized in net (loss) income	$ 48	$ 1	12
Notional amount	2,306	1,325
Foreign exchange swaps | Not Designated as Hedging Instrument
Disclosure of risk management strategy related to hedge accounting [line items]
Notional amount	718	283
Available-for-sale investments
Disclosure of risk management strategy related to hedge accounting [line items]
Reclassification adjustments for amounts recognized in net (loss) income	2	$ 9	$ 0
Gain (loss) expected to be reclassed in the next twelve months	$ 20

SEGMENTED INFORMATION (Details

SEGMENTED INFORMATION (Details - FFO reconciliation) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of operating segments [line items]
Revenues	$ 2,625	$ 2,452	$ 1,628
Other income	47	64	122
Share of Adjusted EBITDA from equity accounted investments	57	21	26
Direct operating costs	978	1,038	552
Adjusted EBITDA	0	0	0
Management service costs	(82)	(62)	(48)
Interest expense borrowings	(632)	(606)	(429)
Current income taxes	(39)	(44)	(18)
Distributions to preferred limited partners	(28)	(15)	(1)
Distributions attributable to Preferred equity	(26)	(25)	(30)
Share of interest and cash taxes from equity accounted investments	(22)	(12)	(6)
Share of Funds From Operations attributable to non-controlling interests	(341)	(316)	(225)
Funds From Operations	0	0	0
Depreciation	782	781	616
Unrealized financial instruments loss	33	4	9
Deferred income tax (recovery) expense	(49)	97	80
Other	(28)	(38)	(63)
Share of earnings from associates	(33)	(9)	(10)
Net income attributable to non-controlling interest	288	251	156
Net Income Loss Attributable To Unit Holders	(56)	(65)	2
Colombia
Disclosure of operating segments [line items]
Revenues	797	819	0
Europe
Disclosure of operating segments [line items]
Revenues	111	136	138
Brazil
Disclosure of operating segments [line items]
Revenues	366	269	265
Attributable to Unitholders
Disclosure of operating segments [line items]
Revenues	1,679	1,481	1,296
Other income	40	47	76
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(577)	(586)	(465)
Adjusted EBITDA	1,142	942	907
Management service costs	82	62	48
Interest expense borrowings	407	402	346
Current income taxes	18	19	15
Distributions to preferred limited partners	(28)	(15)	(1)
Distributions attributable to Preferred equity	(26)	(25)	(30)
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	581	419	467
Depreciation	539	540	462
Unrealized financial instruments loss	(29)	(3)	(13)
Deferred income tax (recovery) expense	(26)	78	78
Other	(43)	(19)	(68)
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	(56)	(65)	2
Attributable to Unitholders | Hydroelectric | North America
Disclosure of operating segments [line items]
Revenues	945	819	819
Other income	1	24	23
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(281)	(295)	(285)
Adjusted EBITDA	665	548	557
Management service costs	0	0	0
Interest expense borrowings	180	177	179
Current income taxes	(1)	4	5
Distributions to preferred limited partners	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	486	367	373
Depreciation	222	244	218
Unrealized financial instruments loss	(3)	1	1
Deferred income tax (recovery) expense	(67)	31	36
Other	(20)	(27)	14
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	174	128	206
Attributable to Unitholders | Hydroelectric | Colombia
Disclosure of operating segments [line items]
Revenues	191	192	0
Other income	2	3	0
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(94)	(107)	0
Adjusted EBITDA	99	88	0
Management service costs	0	0	0
Interest expense borrowings	42	36	0
Current income taxes	5	6	0
Distributions to preferred limited partners	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	52	46	0
Depreciation	26	31	0
Unrealized financial instruments loss	(3)	0	0
Deferred income tax (recovery) expense	(10)	6	0
Other	6	4	0
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	19	25	0
Attributable to Unitholders | Hydroelectric | Brazil
Disclosure of operating segments [line items]
Revenues	243	187	203
Other income	12	13	28
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(77)	(70)	(67)
Adjusted EBITDA	178	130	164
Management service costs	0	0	0
Interest expense borrowings	18	24	18
Current income taxes	12	9	10
Distributions to preferred limited partners	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	148	97	136
Depreciation	141	125	113
Unrealized financial instruments loss	0	0	0
Deferred income tax (recovery) expense	2	7	4
Other	(8)	(5)	(8)
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	1	(26)	19
Attributable to Unitholders | Wind | North America
Disclosure of operating segments [line items]
Revenues	161	151	150
Other income	0	0	12
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(42)	(36)	(38)
Adjusted EBITDA	119	115	124
Management service costs	0	0	0
Interest expense borrowings	45	41	48
Current income taxes	0	0	0
Distributions to preferred limited partners	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	74	74	76
Depreciation	89	80	83
Unrealized financial instruments loss	(1)	0	2
Deferred income tax (recovery) expense	45	49	16
Other	(3)	4	(30)
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	26	47	(19)
Attributable to Unitholders | Wind | Europe
Disclosure of operating segments [line items]
Revenues	46	56	56
Other income	0	0	8
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(20)	(24)	(20)
Adjusted EBITDA	26	32	44
Management service costs	0	0	0
Interest expense borrowings	10	14	12
Current income taxes	1	0	0
Distributions to preferred limited partners	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	15	18	32
Depreciation	24	38	32
Unrealized financial instruments loss	(12)	0	0
Deferred income tax (recovery) expense	6	6	2
Other	(5)	6	(1)
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	(20)	(8)	1
Attributable to Unitholders | Wind | Brazil
Disclosure of operating segments [line items]
Revenues	26	17	9
Other income	0	0	0
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(4)	(4)	(1)
Adjusted EBITDA	22	13	8
Management service costs	0	0	0
Interest expense borrowings	6	7	3
Current income taxes	0	0	0
Distributions to preferred limited partners	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	16	6	5
Depreciation	8	4	4
Unrealized financial instruments loss	0	0	0
Deferred income tax (recovery) expense	0	0	0
Other	2	(1)	0
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	10	1	1
Attributable to Unitholders | Solar, Storage and Other
Disclosure of operating segments [line items]
Revenues	67	58	59
Other income	6	(1)	0
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(34)	(26)	(31)
Adjusted EBITDA	39	31	28
Management service costs	0	0	0
Interest expense borrowings	17	12	5
Current income taxes	1	0	0
Distributions to preferred limited partners	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	21	19	23
Depreciation	29	18	12
Unrealized financial instruments loss	0	2	(1)
Deferred income tax (recovery) expense	1	0	0
Other	(6)	(2)	(4)
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	(13)	1	6
Attributable to Unitholders | Corporate
Disclosure of operating segments [line items]
Revenues	0	1	0
Other income	19	8	5
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(25)	(24)	(23)
Adjusted EBITDA	(6)	(15)	(18)
Management service costs	82	62	48
Interest expense borrowings	89	91	81
Current income taxes	0	0	0
Distributions to preferred limited partners	(28)	(15)	(1)
Distributions attributable to Preferred equity	(26)	(25)	(30)
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	(231)	(208)	(178)
Depreciation	0	0	0
Unrealized financial instruments loss	(10)	(6)	(15)
Deferred income tax (recovery) expense	(3)	(21)	20
Other	(9)	2	(39)
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	0	0	0
Net Income Loss Attributable To Unit Holders	(253)	(233)	(212)
Contribution from equity accounted investments
Disclosure of operating segments [line items]
Revenues	(74)	(37)	(44)
Other income	(11)	0	0
Share of Adjusted EBITDA from equity accounted investments	57	21	26
Direct operating costs	28	16	18
Adjusted EBITDA	0	0	0
Management service costs	0	0	0
Interest expense borrowings	(21)	(12)	(6)
Current income taxes	(1)	0	0
Distributions to preferred limited partners	0	0	0
Distributions attributable to Preferred equity	0	0	0
Share of interest and cash taxes from equity accounted investments	(22)	(12)	(6)
Share of Funds From Operations attributable to non-controlling interests	0	0	0
Funds From Operations	0	0	0
Depreciation	(22)	(11)	(9)
Unrealized financial instruments loss	1	(2)	1
Deferred income tax (recovery) expense	(3)	0	0
Other	13	0	0
Share of earnings from associates	(33)	(9)	(10)
Net income attributable to non-controlling interest	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	1,020	1,008	376
Other income	18	17	46
Share of Adjusted EBITDA from equity accounted investments	0	0	0
Direct operating costs	(429)	(468)	(105)
Adjusted EBITDA	609	557	317
Management service costs	0	0	0
Interest expense borrowings	246	216	89
Current income taxes	22	25	3
Distributions to preferred limited partners	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	(341)	(316)	(225)
Funds From Operations	0	0	0
Depreciation	265	252	161
Unrealized financial instruments loss	(5)	1	3
Deferred income tax (recovery) expense	(20)	19	2
Other	2	(19)	0
Share of earnings from associates	0	0	0
Net income attributable to non-controlling interest	288	251	156
Net Income Loss Attributable To Unit Holders	$ 0	$ 0	$ 0

SEGMENTED INFORMATION (Detail75

SEGMENTED INFORMATION (Details - Balance Sheet) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	$ 27,096	$ 25,257	$ 18,358	$ 18,566
Total assets	30,904	27,737
Total borrowings	11,766	10,182	7,338
Total liabilities	16,622	15,065
For the year ended December 31: Additions to Property Plant and Equipment	354	358
Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	18,429	16,592
Total assets	19,962	17,727
Total borrowings	8,439	7,077
Total liabilities	11,979	10,642
For the year ended December 31: Additions to Property Plant and Equipment	220	222
Contribution from equity accounted investments
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	(1,451)	(428)
Total assets	(1,040)	(280)
Total borrowings	(848)	(232)
Total liabilities	(1,039)	(280)
For the year ended December 31: Additions to Property Plant and Equipment	(10)	(10)
Attributable to non-controlling interests
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	10,118	9,093
Total assets	11,982	10,290
Total borrowings	4,175	3,337
Total liabilities	5,682	4,703
For the year ended December 31: Additions to Property Plant and Equipment	144	146
Hydroelectric
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	22,399	21,569	14,847	15,210
Hydroelectric | North America | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	11,396	10,922
Total assets	11,709	11,219
Total borrowings	3,049	2,946
Total liabilities	5,237	5,414
For the year ended December 31: Additions to Property Plant and Equipment	90	86
Hydroelectric | Colombia | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	1,303	1,273
Total assets	1,574	1,577
Total borrowings	447	467
Total liabilities	801	824
For the year ended December 31: Additions to Property Plant and Equipment	8	9
Hydroelectric | Brazil | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	1,908	1,895
Total assets	2,149	2,059
Total borrowings	200	194
Total liabilities	380	340
For the year ended December 31: Additions to Property Plant and Equipment	59	79
Wind
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	3,751	3,313	$ 3,233	$ 3,315
Wind | North America | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	1,798	1,327
Total assets	1,888	1,389
Total borrowings	1,005	727
Total liabilities	1,338	990
For the year ended December 31: Additions to Property Plant and Equipment	6	3
Wind | Europe | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	482	545
Total assets	532	587
Total borrowings	233	249
Total liabilities	334	337
For the year ended December 31: Additions to Property Plant and Equipment	34	18
Wind | Brazil | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	304	139
Total assets	443	153
Total borrowings	192	50
Total liabilities	208	51
For the year ended December 31: Additions to Property Plant and Equipment	0	1
Solar, Storage and Other | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	1,227	491
Total assets	1,456	561
Total borrowings	752	215
Total liabilities	877	268
For the year ended December 31: Additions to Property Plant and Equipment	13	18
Corporate | Attributable to Unitholders
Disclosure of operating segments [line items]
Property, plant and equipment, at fair value	0	0
Total assets	180	182
Total borrowings	2,552	2,229
Total liabilities	2,786	2,418
For the year ended December 31: Additions to Property Plant and Equipment	$ 10	$ 8

SEGMENTED INFORMATION (Detail76

SEGMENTED INFORMATION (Details - Geographical Information) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of operating segments [line items]
Revenues	$ 2,625	$ 2,452	$ 1,628
Consolidated property, plant and equipment and equity-accounted investments	27,817	25,463
United States
Disclosure of operating segments [line items]
Revenues	871	786	799
Consolidated property, plant and equipment and equity-accounted investments	11,131	10,163
Colombia
Disclosure of operating segments [line items]
Revenues	797	819	0
Consolidated property, plant and equipment and equity-accounted investments	5,401	5,275
Canada
Disclosure of operating segments [line items]
Revenues	480	442	426
Consolidated property, plant and equipment and equity-accounted investments	5,810	5,845
Brazil
Disclosure of operating segments [line items]
Revenues	366	269	265
Consolidated property, plant and equipment and equity-accounted investments	3,479	2,922
Europe
Disclosure of operating segments [line items]
Revenues	111	136	$ 138
Consolidated property, plant and equipment and equity-accounted investments	1,332	1,258
Other
Disclosure of operating segments [line items]
Consolidated property, plant and equipment and equity-accounted investments	$ 664	$ 0

OTHER INCOME (Details)

OTHER INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Other income [line items]
Interest income and other	$ 32	$ 41	$ 21
Gain on available for sale investments	15	0	0
Gains on settlement of foreign currency contracts	0	23	31
Gains on disposal	0	0	53
Compensation related to expired Brazilian concession agreements	0	0	17
Other Income, net	$ 47	$ 64	122
Brookfield Renewable
Other income [line items]
Gains on disposal			$ 12
102 MW wind facility California | Brookfield Renewable
Other income [line items]
Percentage of equity interest			22.00%

DIRECT OPERATING COSTS (Details

DIRECT OPERATING COSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Direct Operating Costs [Abstract]
Operations, maintenance and administration	$ 567	$ 553	$ 396
Water royalties, property taxes and other	161	149	119
Fuel and power purchases	226	313	15
Energy marketing fees	24	23	22
Direct operating costs, net	$ 978	$ 1,038	$ 552

OTHER (Details)

OTHER (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Other [Abstract]
Transaction costs	$ (9)	$ (22)	$ (6)
Change in fair value of property, plant and equipment	(33)	(36)	(45)
Unrealized loss on available-for-sale securities	0	0	(25)
Other	14	20	13
Other expenses, net	$ (28)	$ (38)	$ (63)

FOREIGN CURRENCY TRANSLATION (D

FOREIGN CURRENCY TRANSLATION (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Foreign currency translation on
Property, plant and equipment, at fair value	[1]	$ 506	$ 1,186	$ (1,975)
Long-term debt and credit facilities		(282)	(244)	697
Other assets and liabilities		48	201	(62)
Foreign currency translation, net		$ 190	$ 986	$ (1,138)
[1]	Includes intangible assets of $ 13 million (201 6 : $ 1 4 million and 2015: $ 13 million ) and construction work in process (“CWIP”) of $ 601 million (201 6 : $ 663 million and 2015: $ 405 million ).

INCOME TAXES (Details - Compone

INCOME TAXES (Details - Components of tax PL) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Current tax expense (income) and adjustments for current tax of prior periods [abstract]
Current	$ (39)	$ (44)	$ (18)
Income tax (expense) recovery
Income taxes - origination and reversal of temporary differences	8	71	87
Relating to change in tax rates / imposition of new tax laws	(42)	35	6
Relating to unrecognized temporary differences and tax losses	(15)	(9)	(15)
Deferred taxes, net	(49)	97	80
Total Income Tax recovery (expense)	$ (88)	$ 53	$ 60

INCOME TAXES (Details - Compo82

INCOME TAXES (Details - Components of tax OCI) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Deferred income tax attributed to
Financial instruments designated as cash flow hedges	$ (4)	$ 2	$ 8
Other components of deferred tax expense (income)	15	(7)	(17)
Revaluation surplus
Origination and reversal of temporary differences	(248)	(55)	(263)
Income tax relating to changes in revaluation surplus of other comprehensive income for tax rate changes or imposition of new taxes	586	19	(19)
Total deferred income taxes	$ 349	$ (41)	$ (291)

INCOME TAXES (Details - Expense

INCOME TAXES (Details - Expense reconciliation) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Effective income tax [abstract]
Statutory income tax (expense) recovery	$ (50)	$ 5	$ (15)
(Reduction) increase resulting from
Increase decrease in tax assets not recognised	(15)	(9)	(15)
Deemed profit method difference in Brazil	1	(11)	10
Differences between statutory rate and future tax rate	(38)	54	68
Income or losses recorded not taxable to Brookfield Renewable	14	14	14
Other	0	0	(2)
Total Income Tax recovery (expense)	$ (88)	$ 53	$ 60
Effective income tax rate	63.31%	384.03%

INCOME TAXES (Details - Unrecog

INCOME TAXES (Details - Unrecognized deferred tax) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
2018 to 2022
Disclosure of deductible temporary differences for which no deferred tax asset is recognised [line items]
Unrecognized deferred tax assets	$ 8	$ 0
2023 and Thereafter
Disclosure of deductible temporary differences for which no deferred tax asset is recognised [line items]
Unrecognized deferred tax assets	$ 108	$ 98

INCOME TAXES (Details - Reconci

INCOME TAXES (Details - Reconciliation net labilities) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Deferred tax assets and liabilities [line items]
Recognized in Net income (loss)	$ (49)	$ 97	$ 80
Deferred tax liability related to property, plant and equipment revaluations	2,561	2,948
The taxable temporary difference attributable to Brookfield Renewables interest in its subsidiaries	1,549	1,380
Net deferred tax liability decreased	546
Net decrease in tax liability recorded as tax recovery in the other comprehensive income	587
Noncapital losses
Deferred tax assets and liabilities [line items]
Balance, beginning of year	499	458	403
Recognized in Net income (loss)	(97)	24	73
Recognized in equity	13	17	(1)
Business combination	79	0	5
Foreign exchange	14	0	(22)
Balance, end of year	508	499	458
Amount available for future deductions
Deferred tax assets and liabilities [line items]
Balance, beginning of year	56	65	88
Recognized in Net income (loss)	(5)	(10)	(11)
Recognized in equity	0	0	0
Business combination	0	0	0
Foreign exchange	4	1	(12)
Balance, end of year	55	56	65
Difference between tax and carrying value
Deferred tax assets and liabilities [line items]
Balance, beginning of year	(4,207)	(3,061)	(2,986)
Recognized in Net income (loss)	53	83	16
Recognized in equity	341	(48)	(279)
Business combination	(63)	(1,020)	(35)
Foreign exchange	(98)	(161)	223
Balance, end of year	(3,974)	(4,207)	(3,061)
Deferred tax liability asset
Deferred tax assets and liabilities [line items]
Balance, beginning of year	(3,652)	(2,538)	(2,495)
Recognized in Net income (loss)	(49)	97	78
Recognized in equity	354	(31)	(280)
Business combination	16	(1,020)	(30)
Foreign exchange	(80)	(160)	189
Balance, end of year	(3,411)	$ (3,652)	$ (2,538)
Net deferred tax liability decreased	$ 41

PROPERTY, PLANT AND EQUIPMENT86

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Continuity) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016		Dec. 31, 2015
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1		$ 25,257	$ 18,358		$ 18,566
Additions	[1]	354	358		289
Acquisitions through business combinations	[1]	1,245	5,741		1,160
Disposals property plant and equipment	[1]	(338)			(230)
Items recognized through OCI
Change in fair value	[1]	887	431		1,209
Foreign exchange	[1]	506	1,186		(1,975)
Items recognized through net income
Change in fair value	[1]	(33)	(36)		(45)
Depreciation	[1]	(782)	(781)		(616)
Balance, as at Dec 31		27,096	25,257		18,358
Other intangible assets		13	14		13
Construction in progress		601	663		405
Hydroelectric
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1		21,569	14,847		15,210
Additions		253	269		183
Acquisitions through business combinations		0	5,731		307
Items recognized through OCI
Change in fair value		828	190		1,141
Foreign exchange		332	1,114		(1,585)
Items recognized through net income
Change in fair value		(20)	(17)		(2)
Depreciation		(563)	(565)		(407)
Balance, as at Dec 31		22,399	21,569		14,847
Wind
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1		3,313	3,233		3,315
Additions		95	71		51
Acquisitions through business combinations		618	10		624
Disposals property plant and equipment		(338)			(230)
Items recognized through OCI
Change in fair value		91	187		52
Foreign exchange		177	21		(336)
Items recognized through net income
Change in fair value		(8)	(10)		(43)
Depreciation		(197)	(199)		(200)
Balance, as at Dec 31		3,751	3,313		3,233
Other
Disclosure of detailed information about property, plant and equipment [line items]
Balance, as at Jan 1		375	278	[2]	41	[2]
Additions	[2]	6	18		55
Acquisitions through business combinations	[2]	627	0		229
Items recognized through OCI
Change in fair value	[2]	(32)	54		16
Foreign exchange	[2]	(3)	51		(54)
Items recognized through net income
Change in fair value	[2]	(5)	(9)		0
Depreciation	[2]	(22)	(17)		(9)
Balance, as at Dec 31		$ 946	$ 375		$ 278	[2]
[1]	Includes intangible assets of $ 13 million (201 6 : $ 1 4 million and 2015: $ 13 million ) and construction work in process (“CWIP”) of $ 601 million (201 6 : $ 663 million and 2015: $ 405 million ).
[2]	Includes solar, storage, biomass and Co-gen.

PROPERTY, PLANT AND EQUIPMENT87

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Rates)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
North America
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Exit date	2,037	2,036
North America | Bottom of range
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Terminal capitalization rate	6.20%	6.30%
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%	6.60%
North America | Top of range
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Terminal capitalization rate	7.50%	6.90%
North America | Top of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	6.00%	5.50%
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]
Terminal capitalization rate	12.60%
Exit date	2,037	2,031
Colombia | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	11.30%
Colombia | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	12.60%
Europe
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Exit date	2,031	2,031
Europe | Bottom of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	4.10%	4.10%
Europe | Bottom of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	5.90%	5.90%
Europe | Top of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	4.50%	5.00%
Europe | Top of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	6.30%	6.80%
Brazil
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Exit date	2,032	2,031
Brazil | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate		9.20%
Brazil | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate		10.50%
Brazil | Bottom of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	8.90%
Brazil | Bottom of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	10.20%
Brazil | Top of range | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	9.20%
Brazil | Top of range | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Discount rate	10.50%

PROPERTY, PLANT AND EQUIPMENT88

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Sensitivity) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment	[1]	$ 887	$ 431	$ 1,209
Hydroelectric
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		828	190	$ 1,141
Impact Of Five Percent Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		1,020	630
Impact Of Five Percent Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(1,020)	(630)
25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(910)	(740)
25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(230)	(180)
25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		970	800
25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		240	190
North America | Impact Of Five Percent Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		620	540
North America | Impact Of Five Percent Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(620)	(540)
North America | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(710)	(670)
North America | 25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(180)	(180)
North America | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		770	730
North America | 25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		190	190
Colombia | Impact Of Five Percent Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ 310
Useful life		310,000,000
Colombia | Impact Of Five Percent Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ (310)
Colombia | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(130)
Colombia | 25 bps increase | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(50)
Colombia | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		130
Colombia | 25 bps decrease | Terminal capitalization rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		50
Europe | Impact Of Five Percent Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ 20	20
Useful life		20,000,000
Europe | Impact Of Five Percent Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ (20)	(20)
Europe | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(20)	(20)
Europe | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ 20	$ 20
Brazil | Hydroelectric
Changes in Property Plant And Equipment [Line Items]
Useful life		15	15
Additional fair value of Brazil hydro assets		$ 1,500
Additional useful life		20
Brazil | Impact Of Five Percent Increase | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ 70	$ 70
Useful life		70,000,000
Brazil | Impact Of Five Percent Decrease | Future electricity prices
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ (70)	(70)
Brazil | 25 bps increase | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		(50)	(50)
Brazil | 25 bps decrease | Discount rate
Changes in Property Plant And Equipment [Line Items]
Revaluation increase (decrease), property, plant and equipment		$ 50	$ 50
[1]	Includes intangible assets of $ 13 million (201 6 : $ 1 4 million and 2015: $ 13 million ) and construction work in process (“CWIP”) of $ 601 million (201 6 : $ 663 million and 2015: $ 405 million ).

PROPERTY, PLANT AND EQUIPMENT89

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Prices and Generation) $ in Millions		12 Months Ended
		Dec. 31, 2017USD ($)$ / MWhCOP / MWh€ / MWhBRL / MWh	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Change in fair value | $	[1]	$ 887	$ 431	$ 1,209
North America | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		58.00%
Eletricity prices | $ / MWh		84
North America | 1-10 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | $ / MWh		63
North America | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		42.00%
Eletricity prices | $ / MWh		88
North America | 11-20 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | $ / MWh		112
Colombia | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		17.00%
Eletricity prices | COP / MWh		211,000
Colombia | 1-10 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | COP / MWh		238,000
Colombia | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		0.00%
Eletricity prices | COP / MWh		0
Colombia | 11-20 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | COP / MWh		339,000
Europe | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		78.00%
Eletricity prices | € / MWh		90
Europe | 1-10 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | € / MWh		78
Europe | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		35.00%
Eletricity prices | € / MWh		107
Europe | 11-20 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | € / MWh		95
Brazil | 1-10 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		66.00%
Eletricity prices | BRL / MWh		274
Brazil | 1-10 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | BRL / MWh		309
Brazil | 11-20 years | Contracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Percentage of generation		57.00%
Eletricity prices | BRL / MWh		407
Brazil | 11-20 years | Uncontracted
Disclosure of significant unobservable inputs used in fair value measurement of assets [line items]
Eletricity prices | BRL / MWh		458
[1]	Includes intangible assets of $ 13 million (201 6 : $ 1 4 million and 2015: $ 13 million ) and construction work in process (“CWIP”) of $ 601 million (201 6 : $ 663 million and 2015: $ 405 million ).

PROPERTY, PLANT AND EQUIPMENT90

PROPERTY, PLANT AND EQUIPMENT, AT FAIR VALUE (Details - Historical costs) - USD ($) $ in Millions	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	$ 15,768
Hydroelectric
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	12,740	12,761
Wind
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	3,030	2,688
Other
Property Plant and Equipment carrying amount at cost of revalued assets [Line Items]
Property, plant and equipment, revalued assets, at cost	$ 933	$ 319

LONG-TERM DEBT AND CREDIT FAC91

LONG-TERM DEBT AND CREDIT FACILITIES (Details - Composition of debt) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure Of Detailed Information About Borrowings Line Items
Notional amount	$ 11,842	$ 10,260
Long-term debt and credit facilities	10,090	9,148
Current portion of long-term debt	1,676	1,034
Unamortised Financing Fees	77	80	$ 59
Unamortised Premiums	1	2
Long-term debt and credit facilities	$ 11,766	$ 10,182	7,338
Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	4.50%	4.50%
Weighted Average Borrowings Term	6.4	7.4
Notional amount	$ 1,670	$ 1,562
Estimated fair value	1,754	1,677
Unamortised Financing Fees	$ 5	$ 6	5	$ 5
Credit facilities
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	2.60%	1.90%
Weighted Average Borrowings Term	4.5	4.5
Notional amount	$ 887	$ 673
Estimated fair value	$ 887	$ 673
Sudsidiary
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	6.50%	6.40%
Weighted Average Borrowings Term	9	9
Notional amount	$ 9,285	$ 8,025
Estimated fair value	9,838	8,520
Unamortised Financing Fees	$ 72	$ 74	$ 54	$ 66
Sudsidiary | Hydroelectric
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	6.30%	6.90%
Weighted Average Borrowings Term	8.8	7.8
Notional amount	$ 6,392	$ 6,249
Estimated fair value	$ 6,813	$ 6,600
Sudsidiary | Wind
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	5.80%	4.60%
Weighted Average Borrowings Term	9.7	13.1
Notional amount	$ 2,211	$ 1,735
Estimated fair value	$ 2,343	$ 1,879
Sudsidiary | Solar and Other
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	11.00%	8.90%
Weighted Average Borrowings Term	8.2	18.8
Notional amount	$ 682	$ 41
Estimated fair value	$ 682	$ 41
Series 3 | Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	5.30%	5.30%
Weighted Average Borrowings Term	0.8	1.8
Notional amount	$ 159	$ 149
Estimated fair value	$ 163	$ 158
Series 4 | Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	5.80%	5.80%
Weighted Average Borrowings Term	18.9	19.9
Notional amount	$ 119	$ 111
Estimated fair value	$ 144	$ 132
Series 7 | Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	5.10%	5.10%
Weighted Average Borrowings Term	2.8	3.8
Notional amount	$ 358	$ 334
Estimated fair value	$ 382	$ 368
Series 8 | Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	4.80%	4.80%
Weighted Average Borrowings Term	4.1	5.1
Notional amount	$ 318	$ 298
Estimated fair value	$ 344	$ 331
Series 9 | Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	3.80%	3.80%
Weighted Average Borrowings Term	7.4	8.4
Notional amount	$ 318	$ 298
Estimated fair value	$ 321	$ 308
Series 10 | Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Weighted Average Interest Rate	3.60%	3.60%
Weighted Average Borrowings Term	9	10
Notional amount	$ 398	$ 372
Estimated fair value	$ 400	$ 380

LONG-TERM DEBT AND CREDIT FAC92

LONG-TERM DEBT AND CREDIT FACILITIES (Details - Changes over year) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
LONG-TERM DEBT AND CREDIT FACILITIES [Abstract]
Cash flows from financing activities	$ 267	$ 1,502
Non-cash
Acquisition	1,188	1,104
Disposal	(173)	0
Other	$ 302	$ 238

LONG-TERM DEBT AND CREDIT FAC93

LONG-TERM DEBT AND CREDIT FACILITIES (Details - Maturity schedule) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	$ 11,766	$ 10,182	$ 7,338
Corporate borrowings and credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	2,557
Subsidiary borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	11,842
Subsidiary borrowings | Hydroelectric
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	6,392
Subsidiary borrowings | Wind
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	2,211
Subsidiary borrowings | Solar and Other
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	682
Equity-accounted investments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	4,659
2018 | Corporate borrowings and credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	159
2018 | Subsidiary borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	1,676
2018 | Subsidiary borrowings | Hydroelectric
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	206
2018 | Subsidiary borrowings | Wind
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	665
2018 | Subsidiary borrowings | Solar and Other
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	646
2018 | Equity-accounted investments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	110
2019 | Corporate borrowings and credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	202
2019 | Subsidiary borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	686
2019 | Subsidiary borrowings | Hydroelectric
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	366
2019 | Subsidiary borrowings | Wind
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	115
2019 | Subsidiary borrowings | Solar and Other
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	3
2019 | Equity-accounted investments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	116
2020 | Corporate borrowings and credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	377
2020 | Subsidiary borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	1,515
2020 | Subsidiary borrowings | Hydroelectric
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	1,013
2020 | Subsidiary borrowings | Wind
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	122
2020 | Subsidiary borrowings | Solar and Other
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	3
2020 | Equity-accounted investments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	112
2021 | Corporate borrowings and credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	0
2021 | Subsidiary borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	949
2021 | Subsidiary borrowings | Hydroelectric
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	822
2021 | Subsidiary borrowings | Wind
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	125
2021 | Subsidiary borrowings | Solar and Other
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	2
2021 | Equity-accounted investments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	716
2022 | Corporate borrowings and credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	984
2022 | Subsidiary borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	1,437
2022 | Subsidiary borrowings | Hydroelectric
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	317
2022 | Subsidiary borrowings | Wind
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	132
2022 | Subsidiary borrowings | Solar and Other
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	4
2022 | Equity-accounted investments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	602
Thereafter
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	16,501
Thereafter | Corporate borrowings and credit facilities
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	835
Thereafter | Subsidiary borrowings
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	5,579
Thereafter | Subsidiary borrowings | Hydroelectric
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	3,668
Thereafter | Subsidiary borrowings | Wind
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	1,052
Thereafter | Subsidiary borrowings | Solar and Other
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	24
Thereafter | Equity-accounted investments
Disclosure of maturity analysis for non-derivative financial liabilities [line items]
Borrowings	$ 3,003

LONG-TERM DEBT AND CREDIT FAC94

LONG-TERM DEBT AND CREDIT FACILITIES (Details - Financing fees) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Financing Fees
Unamortised Financing Fees, beginning of year	$ 80	$ 59
Unamortised Financing Fees, end of year	77	80	$ 59
Corporate Borrowings
Financing Fees
Unamortised Financing Fees, beginning of year	6	5	5
Amortisation Finance Fees	(1)	(1)	(1)
Additional Financing Fees	0	2	1
Unamortised Financing Fees, end of year	5	6	5
Sudsidiary
Financing Fees
Unamortised Financing Fees, beginning of year	74	54	66
Amortisation Finance Fees	(14)	(17)	(15)
Additional Financing Fees	16	41	7
Finance Fees Foreign Exchange Translation Other	(4)	(4)	(4)
Unamortised Financing Fees, end of year	$ 72	$ 74	$ 54

LONG-TERM DEBT AND CREDIT FAC95

LONG-TERM DEBT AND CREDIT FACILITIES (Details - Financings during the year) € in Millions, £ in Millions, CAD in Millions, BRL in Millions, $ in Millions	1 Months Ended					12 Months Ended
	Oct. 31, 2017EUR (€)	Jul. 31, 2017USD ($)	Jun. 30, 2017CAD	May 31, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2017BRL	Dec. 31, 2017CAD	Dec. 31, 2017GBP (£)	Dec. 31, 2017USD ($)	Oct. 31, 2017USD ($)	Jun. 30, 2017USD ($)	Dec. 31, 2016USD ($)
Disclosure Of Detailed Information About Borrowings Line Items
Principal value									$ 11,842			$ 10,260
Authorized credit facilities									2,090			1,890
Series 3 medium-term notes
Disclosure Of Detailed Information About Borrowings Line Items
Principal value							CAD 200		159
Borrowings, maturity						November 2,018
Corporate Borrowings
Disclosure Of Detailed Information About Borrowings Line Items
Principal value									$ 1,670			$ 1,562
Borrowings, interest rate						4.50%	4.50%	4.50%	4.50%			4.50%
Borrowings Term						6.4	6.4	6.4	6.4			7.4
Credit facilities
Disclosure Of Detailed Information About Borrowings Line Items
Principal value									$ 887			$ 673
Borrowings, maturity			June 30, 2022
Borrowings, interest rate basis			banker’s acceptance rate, LIBOR or EURIBOR
Borrowings, interest rate						2.60%	2.60%	2.60%	2.60%			1.90%
Borrowings Term						4.5	4.5	4.5	4.5			4.5
Corporate credit facilities
Disclosure Of Detailed Information About Borrowings Line Items
Authorized credit facilities											$ 1,600
Brookfield Asset Management credit facilities
Disclosure Of Detailed Information About Borrowings Line Items
Authorized credit facilities					$ 400
Sudsidiary
Disclosure Of Detailed Information About Borrowings Line Items
Principal value									$ 9,285			$ 8,025
Borrowings, interest rate						6.50%	6.50%	6.50%	6.50%			6.40%
Borrowings Term						9	9	9	9			9
417 MW Hydroeletric facility
Disclosure Of Detailed Information About Borrowings Line Items
Principal value					$ 60
Borrowings, maturity					March 2,022
Borrowings, interest rate					3.75%
44 MW hydroelectric portfolio
Disclosure Of Detailed Information About Borrowings Line Items
Principal value				$ 65
Borrowings, maturity				May 2,027
Borrowings, interest rate				4.86%
11 MW wind asset
Disclosure Of Detailed Information About Borrowings Line Items
Principal value											$ 11
Borrowings, maturity			June 2,024
Borrowings, interest rate			5.28%								5.28%
17 MW hydroeletric facility
Disclosure Of Detailed Information About Borrowings Line Items
Principal value			CAD 55								$ 43
Borrowings, maturity			May 2,044
Borrowings, interest rate			4.49%								4.49%
360 MW hydroelectric portfolio
Disclosure Of Detailed Information About Borrowings Line Items
Principal value		$ 475
Borrowings, maturity		July 2,032
Borrowings, interest rate		4.40%
47 MW wind portfolio
Disclosure Of Detailed Information About Borrowings Line Items
Principal value	€ 78									$ 92
Borrowings, maturity		2,032
Borrowings, interest rate basis	EURIBOR
Working capital facility	€ 6									8
Debt reserve facility	€ 4									4
872 MW hydroelectric portfolio
Disclosure Of Detailed Information About Borrowings Line Items
Principal value										$ 305
Borrowings, maturity	December 2,030
Borrowings, interest rate	4.29%									4.29%
28 MW Hydroelectric facility
Disclosure Of Detailed Information About Borrowings Line Items
Principal value						BRL 166			$ 50
Borrowings, maturity						2,038
28 MW Hydroelectric facility | TJLP
Disclosure Of Detailed Information About Borrowings Line Items
Borrowings, interest rate						2.12%	2.12%	2.12%	2.12%
16 MW wind facility
Disclosure Of Detailed Information About Borrowings Line Items
Principal value								£ 17	$ 22
Borrowings, maturity						2,035
16 MW wind facility | LIBOR
Disclosure Of Detailed Information About Borrowings Line Items
Borrowings, interest rate						2.20%	2.20%	2.20%	2.20%

LONG-TERM DEBT AND CREDIT FAC96

LONG-TERM DEBT AND CREDIT FACILITIES (Details - Available credit facilities) - USD ($) $ in Thousands	1 Months Ended		12 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2017	Dec. 31, 2016
Disclosure of credit facilities line item
Authorized credit facilities			$ 2,090,000	$ 1,890,000
Draws on credit facilities			(685,000)	(673,000)
Letters of credit issued			(193,000)	(250,000)
Undrawn borrowing facilities			1,212,000	$ 967,000
Credit facilities
Disclosure of credit facilities line item
Draws on credit facilities			202,000
Borrowings, maturity	June 30, 2022
Brookfield Asset Management credit facilities
Disclosure of credit facilities line item
Authorized credit facilities		$ 400,000
Draws on credit facilities			$ 202,000
Interest rate margin		2.00%
Extension of Maturity Date		December 2,018	June 2,019
Brookfield Asset Management credit facilities | LIBOR
Disclosure of credit facilities line item
Interest rate margin			1.50%
Corporate credit facilities
Disclosure of credit facilities line item
Authorized credit facilities	$ 1,600,000
Interest rate margin	1.20%

NON-CONTROLLING INTERESTS (Deta

NON-CONTROLLING INTERESTS (Details - Summary) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Participating Non-controlling Interests Operating Subsidiaries
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	$ 6,298	$ 5,589
General partnership interest in a holding subsidiary held by Brookfield
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	58	55
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	2,843	2,680
Preferred equity
Disclosure of Non Controlling Interest [Line Items]
Non controlling Interests	$ 616	$ 576

NON-CONTROLLING INTERESTS (De98

NON-CONTROLLING INTERESTS (Details - Continuity) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of subsidiaries [line items]
Profit Loss Attributable To Noncontrolling Interests	$ 288	$ 251	$ 156
Capital contributions	294	2,621	460
Acquisition	525	1,417
Other			1
Subsidiaries with material non-controlling interests
Disclosure of subsidiaries [line items]
Beginning Balance	5,589
Profit Loss Attributable To Noncontrolling Interests	53	65	69
Ending Balance	6,298	5,589
Brookfield Infrastructre Fund I
Disclosure of subsidiaries [line items]
Beginning Balance	963	958	914
Profit Loss Attributable To Noncontrolling Interests	(29)	(18)	26
Other comprehensive income, attributable to non-controlling interests	(76)	46	89
Capital contributions	0	0
Acquisition		0
Distributions	(8)	(23)	(70)
MTO adjustments	0	0
Other	0		(1)
Ending Balance	$ 850	963	958
Brookfield Infrastructre Fund I | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	75.00%
Brookfield Infrastructre Fund I | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	80.00%
Brookfield Infrastructre Fund III
Disclosure of subsidiaries [line items]
Beginning Balance	$ 1,085
Profit Loss Attributable To Noncontrolling Interests	33	15
Other comprehensive income, attributable to non-controlling interests	111	0	0
Capital contributions	186	1,074
Acquisition	525
Distributions	(88)	(7)	0
MTO adjustments	1	3
Other	1		0
Ending Balance	$ 1,852	1,085
Brookfield Infrastructre Fund III | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	69.00%
Brookfield Infrastructre Fund III | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	71.00%
Brookfield Infrastructre Fund II
Disclosure of subsidiaries [line items]
Beginning Balance	$ 1,654	1,441	937
Profit Loss Attributable To Noncontrolling Interests	(13)	(16)	27
Other comprehensive income, attributable to non-controlling interests	269	228	144
Capital contributions	89	74	460
Acquisition		0
Distributions	(317)	(73)	(126)
MTO adjustments	0	0
Other	0		(1)
Ending Balance	$ 1,682	1,654	1,441
Brookfield Infrastructre Fund II | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	50.00%
Brookfield Infrastructre Fund II | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	60.00%
The Cataylst Group
Disclosure of subsidiaries [line items]
Beginning Balance	$ 127	121	126
Profit Loss Attributable To Noncontrolling Interests	12	16	14
Other comprehensive income, attributable to non-controlling interests	2	2	(12)
Capital contributions	0	0
Acquisition		0
Distributions	(7)	(12)	(7)
MTO adjustments	0	0
Other	0		0
Ending Balance	$ 134	127	121
Interests held by third parties	25.00%
The Cataylst Group | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	25.00%
Brookfield Energia Renovavel
Disclosure of subsidiaries [line items]
Capital contributions		0
Acquisition		0
Isagen Institutional Investors
Disclosure of subsidiaries [line items]
Beginning Balance	$ 1,675
Profit Loss Attributable To Noncontrolling Interests	47	47
Other comprehensive income, attributable to non-controlling interests	78	148	0
Capital contributions	19	1,473
Acquisition		0
Distributions	(115)	0	0
MTO adjustments	2	7
Other	2		0
Ending Balance	$ 1,701	1,675
Interests held by third parties	53.00%
Isagen Institutional Investors | Brookfield and co-investors
Disclosure of subsidiaries [line items]
Owership percentage	99.50%
Number of additional shares acquired	3,358,523
Isagen Public non-controlling interests
Disclosure of subsidiaries [line items]
Beginning Balance	$ 14
Profit Loss Attributable To Noncontrolling Interests	0	19
Other comprehensive income, attributable to non-controlling interests	(1)	205	0
Capital contributions	0	0
Acquisition		1,417
Distributions	0	0	0
MTO adjustments	(9)	(1,627)
Other	(9)		0
Ending Balance	$ 9	14
Interests held by third parties	0.50%
Other
Disclosure of subsidiaries [line items]
Beginning Balance	$ 71	67	85
Profit Loss Attributable To Noncontrolling Interests	3	2	2
Other comprehensive income, attributable to non-controlling interests	0	6	(17)
Capital contributions	0	0
Acquisition		0
Distributions	(4)	(4)	(5)
MTO adjustments	0	0
Other	0		2
Ending Balance	$ 70	$ 71	$ 67
Other | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	21.00%
Other | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	50.00%

NON-CONTROLLING INTERESTS (De99

NON-CONTROLLING INTERESTS (Details - Summary information) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Disclosure of subsidiaries [line items]
Revenues	$ 2,625	$ 2,452	$ 1,628
Profit Loss	51	40	103
Comprehensive income	1,401	1,369	5
Profit Loss Attributable To Noncontrolling Interests	288	251	156
Property, plant and equipment, at fair value	27,096	25,257	18,358	$ 18,566
Assets	30,904	27,737
Liabilities	16,622	15,065
Borrowings	$ 11,766	10,182	7,338
Subsidiaries with material non-controlling interests
Disclosure of subsidiaries [line items]
Interest held by third parties Isagen total	75.90%
Revenues	$ 1,570	1,550	728
Profit Loss	107	124	147
Comprehensive income	815	988	348
Profit Loss Attributable To Noncontrolling Interests	53	65	69
Property, plant and equipment, at fair value	15,745	14,133
Assets	18,460	15,884
Liabilities	6,411	5,180
Borrowings	8,559	7,107
Non controlling Interests	$ 6,298	5,589
Brookfield Infrastructre Fund I
Disclosure of subsidiaries [line items]
Place of business	United States, Brazil
Revenues	$ 123	118	136
Profit Loss	(34)	(22)	34
Comprehensive income	(133)	37	144
Profit Loss Attributable To Noncontrolling Interests	(29)	(18)	26
Property, plant and equipment, at fair value	1,667	1,807
Assets	1,718	1,865
Liabilities	628	631
Borrowings	556	571
Non controlling Interests	$ 850	963	958	914
Brookfield Infrastructre Fund I | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	75.00%
Brookfield Infrastructre Fund I | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	80.00%
Brookfield Infrastructre Fund II
Disclosure of subsidiaries [line items]
Place of business	United States, Brazil, Europe
Revenues	$ 430	394	402
Profit Loss	(20)	(23)	49
Comprehensive income	529	356	247
Profit Loss Attributable To Noncontrolling Interests	(13)	(16)	27
Property, plant and equipment, at fair value	5,153	4,816
Assets	5,430	5,125
Liabilities	2,422	2,235
Borrowings	2,040	1,881
Non controlling Interests	$ 1,682	1,654	1,441	937
Brookfield Infrastructre Fund II | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	50.00%
Brookfield Infrastructre Fund II | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	60.00%
Brookfield Infrastructre Fund III
Disclosure of subsidiaries [line items]
Interest held by third parties Isagen total	22.90%
Place of business	United States, Brazil, India, China, South Africa
Revenues	$ 53	28
Profit Loss	18	(8)
Comprehensive income	126	(8)	0
Profit Loss Attributable To Noncontrolling Interests	33	15
Property, plant and equipment, at fair value	2,149	848
Assets	3,294	855
Liabilities	1,678	319
Borrowings	1,502	313
Non controlling Interests	$ 1,852	1,085
Brookfield Infrastructre Fund III | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	69.00%
Brookfield Infrastructre Fund III | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	71.00%
The Cataylst Group
Disclosure of subsidiaries [line items]
Interests held by third parties	25.00%
Place of business	United States
Revenues	$ 135	164	160
Profit Loss	47	62	56
Comprehensive income	57	70	8
Profit Loss Attributable To Noncontrolling Interests	12	16	14
Property, plant and equipment, at fair value	964	970
Assets	1,066	1,072
Liabilities	432	466
Borrowings	413	450
Non controlling Interests	$ 134	127	121	$ 126
The Cataylst Group | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	25.00%
Isagen
Disclosure of subsidiaries [line items]
Interest held by third parties Isagen total	0.50%
Place of business	Colombia
Revenues	$ 797	819
Profit Loss	89	110
Comprehensive income	236	502	0
Profit Loss Attributable To Noncontrolling Interests		86
Property, plant and equipment, at fair value	5,401	5,275
Assets	6,526	6,539
Liabilities	3,336	3,396
Borrowings	$ 1,858	1,924
Non controlling Interests		2,391
Isagen | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	76.00%
Other subsidiaries with material noncontrolling interests including Brazil
Disclosure of subsidiaries [line items]
Place of business	United States, Brazil, Canada
Revenues	$ 32	27	30
Profit Loss	7	5	8
Comprehensive income	0	31	(51)
Profit Loss Attributable To Noncontrolling Interests		2	$ 2
Property, plant and equipment, at fair value	411	417
Assets	426	428
Liabilities	63	60
Borrowings	$ 42	41
Non controlling Interests		71
Other subsidiaries with material noncontrolling interests including Brazil | Bottom of range
Disclosure of subsidiaries [line items]
Interests held by third parties	21.00%
Other subsidiaries with material noncontrolling interests including Brazil | Top of range
Disclosure of subsidiaries [line items]
Interests held by third parties	50.00%
Isagen Institutional Investors
Disclosure of subsidiaries [line items]
Interests held by third parties	53.00%
Interest held by third parties Isagen total	52.50%
Profit Loss Attributable To Noncontrolling Interests	$ 47	47
Non controlling Interests	$ 1,701	1,675
Isagen Public non-controlling interests
Disclosure of subsidiaries [line items]
Interests held by third parties	0.50%
Profit Loss Attributable To Noncontrolling Interests	$ 0	19
Non controlling Interests	$ 9	$ 14

NON-CONTROLLING INTERESTS (D100

NON-CONTROLLING INTERESTS (Details - GP REU distributions and summary) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Non-controlling interests [member]
Disclosure of dividends [line items]
Distributions, Dollar	$ 278	$ 256
Disclosure of summary financial information [line items]
Revenues	2,625	2,452	$ 1,628
Comprehensive income	1,401	1,369	$ 5
Net (loss) income attributable to:
Property, plant and equipment, at fair value	27,096	25,257
Assets	30,904	27,737
Liabilities	$ 16,622	$ 15,065
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	180,400,000	166,800,000
Weighted average number of units	173,500,000	156,400,000	143,300,000
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] | Redeemable/Exchangeable partnership units
Carrying value of:
Common units outstanding	129,658,623	129,658,623
Weighted average number of units	129,700,000	129,700,000	129,700,000
Non-controlling interests [member] | Redeemable/Exchangeable partnership units | Brookfield Renewable
Disclosure of dividends [line items]
Owership percentage	100.00%
Non-controlling interests [member] | GP interests
Disclosure of dividends [line items]
Distributions, Dollar	$ 35	$ 24
Carrying value of:
Common units outstanding	2,651,506	2,651,506
Weighted average number of units	2,700,000	2,700,000	2,700,000
General partnership interest in a holding subsidiary held by Brookfield
Disclosure of summary financial information [line items]
Net (loss) income			$ 0
Net (loss) income attributable to:
Non-controlling interests	$ (1)	$ 0	0
Carrying value of:
Non controlling Interests	$ 58	55
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	30	19
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of summary financial information [line items]
Net (loss) income	(23)	(29)	1
Net (loss) income attributable to:
Non-controlling interests	(23)	(29)	$ 1
Carrying value of:
Non controlling Interests	2,843	2,680
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	$ 243	$ 232

NON-CONTROLLING INTERESTS (D101

NON-CONTROLLING INTERESTS (Details - Preferred Equity) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Jun. 30, 2017
Series 1 (C$136)
Disclosure of preference shares [Line Items]
Shares outstanding	5,450
Cumulative dividend rate (%)	3.36%
Earliest permitted redemption date	Apr 30, 2020
Dividends declared for the year ended	$ 4	$ 3
Non controlling Interests	$ 108	101
Series 2 (C$113)
Disclosure of preference shares [Line Items]
Shares outstanding	4,510
Cumulative dividend rate (%)	3.63%
Earliest permitted redemption date	Apr 30, 2020
Dividends declared for the year ended	$ 3	3
Non controlling Interests	$ 90	84
Series 3 (C$249)
Disclosure of preference shares [Line Items]
Shares outstanding	9,960
Cumulative dividend rate (%)	4.40%
Earliest permitted redemption date	Jul 31, 2019
Dividends declared for the year ended	$ 8	8
Non controlling Interests	$ 197	185
Series 5 (C$103)
Disclosure of preference shares [Line Items]
Shares outstanding	4,110
Cumulative dividend rate (%)	5.00%
Earliest permitted redemption date	Apr 30, 2018
Dividends declared for the year ended	$ 4	4
Non controlling Interests	$ 82	76
Series 6 (C$175)
Disclosure of preference shares [Line Items]
Shares outstanding	7,000
Cumulative dividend rate (%)	5.00%
Earliest permitted redemption date	Jul 31, 2018
Dividends declared for the year ended	$ 7	7
Non controlling Interests	$ 139	$ 130
Class A Preference Shares
Disclosure of preference shares [Line Items]
Percentage of units for normal course issuer bid			10.00%

PREFERRED LIMITED PARTNERS E102

PREFERRED LIMITED PARTNERS EQUITY (Details) CAD / shares in Units, CAD in Millions, $ in Millions	1 Months Ended		12 Months Ended
	Feb. 28, 2017CADCAD / sharesshares	Feb. 28, 2017USD ($)	Dec. 31, 2017USD ($)shares	Dec. 31, 2016USD ($)	Jun. 30, 2017
Disclosure of preferred limited partners [Line Items]
Preferred limited partners' equity			$ 616	$ 576
Preferred Limited Partners Unit [Member]
Disclosure of preferred limited partners [Line Items]
Number of shares outstanding | shares			27,890,000
Dividends declared for the year ended				15
Preferred limited partners' equity			$ 511
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 30, 2018
Dividends declared for the year ended			$ 4	3
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 31, 2021
Dividends declared for the year ended			$ 8	7
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 31, 2021
Dividends declared for the year ended			$ 8	5
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%	5.00%
Earliest redemption date			Apr 30, 2022
Dividends declared for the year ended			$ 8	0
Preferred limited partners' equity			$ 187	$ 0
Gross Proceeds From Issuing Shares	CAD 250	$ 190
Dividend rate reset period	April 30, 2022	April 30, 2022
Par Value Per Share | CAD / shares	CAD 25
Number of shares issued | shares	10,000,000
Series 11 (C$250) | Government of Canada Bond yield plus
Disclosure of preferred limited partners [Line Items]
Dividend rate	3.82%	3.82%
Series 11 (C$250) | T-Bill Rate plus
Disclosure of preferred limited partners [Line Items]
Dividend rate			3.82%
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) CAD / shares in Units, $ / shares in Units, CAD in Millions, $ in Millions	1 Months Ended	12 Months Ended
	Feb. 28, 2017$ / shares	Dec. 31, 2017CADshares	Dec. 31, 2017USD ($)shares	Dec. 31, 2016USD ($)shares	Jul. 06, 2017CAD / sharesshares
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		180,388,361	180,388,361
Share issue related cost		CAD 15	$ 11
Gross Proceeds From Issuing Shares		CAD 550	422
Dividends recognised as distributions to owners | $			$ 328	$ 281
Dividends paid, ordinary shares per share | $ / shares	$ 1.87
LP Units | Distribution reinvestment plan
Disclosure of limited partners equity [Line Items]
Number of shares issued		302,037	302,037	298,946
LP Units | Brookfield Asset Management
Disclosure of limited partners equity [Line Items]
Number of shares outstanding		56,068,944	56,068,944	51,125,944
Dividends recognised as distributions to owners | $			$ 101	$ 83
LP Units | Brookfield Asset Management | Private Placement
Disclosure of limited partners equity [Line Items]
Number of shares issued					4,943,000
LP Units | Public shareholders
Disclosure of limited partners equity [Line Items]
Dividends recognised as distributions to owners | $			$ 227	$ 198
LP Units | Public shareholders | Ownership interest in BEP
Disclosure of limited partners equity [Line Items]
Maximum units for normal course issuer bid		9,000,000	9,000,000
Percentage of units for normal course issuer bid		5.00%	5.00%
LP Units | Public shareholders | Bought deal
Disclosure of limited partners equity [Line Items]
Gross Proceeds From Issuing Shares		CAD 350	$ 271
Amount Per Share | CAD / shares					CAD 42.15
Number of shares issued					8,304,000
Redeemable/Exchangeable partnership units
Disclosure of limited partners equity [Line Items]
Issue Of Equity Adjustment | $			62
GP interests
Disclosure of limited partners equity [Line Items]
Issue Of Equity Adjustment | $			$ 1
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) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Changes in goodwill [abstract]
Beginning of year	$ 896
Acquired through business acquisition	0	$ 799
Foreign exchange	5	97
End of year	$ 901	$ 896

CAPITAL MANAGEMENT (Details)

CAPITAL MANAGEMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Mar. 31, 2018	Dec. 31, 2016	Dec. 31, 2015	Nov. 30, 2014
Disclosure of objectives, policies and processes for managing capital [line items]
Current portion of long-term debt	$ 1,676		$ 1,034
Non-current portion of non-current borrowings	10,090		9,148
Total borrowings	11,766		10,182	$ 7,338
Deferred income tax liabilities, net	3,411		3,652
Equity	14,282		12,672	$ 8,763	$ 8,881
Capitalization, net	$ 29,459		$ 26,506
Debt to total capitalization	40.00%		38.00%
Terraform Global
Disclosure of objectives, policies and processes for managing capital [line items]
Non-current portion of non-current borrowings	$ 342
Total borrowings	$ 841
Borrowings, maturity	2,031
Redemption of bonds par value option, percent		101.00%
Redemption of bonds par value actual, percent		107.00%

EQUITY-ACCOUNTED INVESTMENTS (D

EQUITY-ACCOUNTED INVESTMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of joint ventures [line items]
Carrying value	$ 721	$ 206	$ 197
Balance, beginning of year	206	197	273
Share of earnings from equity-accounted investments	2	0	10
Share of OCI: Revaluation of property, plant and equipment	54	7	96
Share of OCI: Other	2	1	0
Dividends received	(31)	(6)	(19)
Capital distributions, net	0	0	(144)
Foreign exchange translation	19	7	(19)
Balance, end of year	$ 721	206	197
First hydro
Disclosure of joint ventures [line items]
Name of joint venture	FHH (Guernsey) Limited
Ownership interest	25.00%
Carrying value	$ 245	0
Balance, beginning of year	0
Balance, end of year	245	0
European Storage
Disclosure of joint ventures [line items]
Acquisition	$ 248	0	0
TerraForm Power
Disclosure of joint ventures [line items]
Name of joint venture	TerraForm Power Inc.(1)
Ownership interest	16.00%
Carrying value	$ 0	0
Balance, beginning of year	0
Acquisition	221	0	$ 0
Balance, end of year	$ 212	0
Bear Swamp Power Co LLC
Disclosure of joint ventures [line items]
Name of joint venture	Bear Swamp Power Co. L.L.C.
Ownership interest	50.00%
Carrying value	$ 173	114
Balance, beginning of year	114
Balance, end of year	$ 173	114
Galera Centrais Eletricas SA
Disclosure of joint ventures [line items]
Ownership interest	50.00%
Carrying value	$ 28	29
Balance, beginning of year	29
Balance, end of year	$ 28	29
Pingston Power Inc
Disclosure of joint ventures [line items]
Ownership interest	50.00%
Carrying value	$ 57	58
Balance, beginning of year	58
Balance, end of year	$ 57	58
Brookfield Infrastructure Fund II Investees
Disclosure of joint ventures [line items]
Principal place of business	United States, Europe
Carrying value	$ 6	5
Balance, beginning of year	5
Balance, end of year	$ 6	$ 5
Brookfield Infrastructure Fund II Investees | Bottom of range
Disclosure of joint ventures [line items]
Ownership interest	14.00%
Brookfield Infrastructure Fund II Investees | Top of range
Disclosure of joint ventures [line items]
Ownership interest	50.00%

EQUITY-ACCOUNTED INVESTMENTS107

EQUITY-ACCOUNTED INVESTMENTS (Details - Summary Information) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of joint ventures [line items]
Current assets	$ 477	$ 45
Property, plant and equipment, at fair value	8,098	864
Other assets	213	70
Current liabilities	687	42
Long-term debt	4,294	463
Other liabilities	958	71
Revenue	310	74	$ 89
Net (loss) income	(24)	0	19
Share of net income (loss): Cash Earnings	57	21	26
Share of net income (loss): Non-cash loss	$ (33)	$ (9)	$ (10)

CASH AND CASH EQUIVALENTS (Deta

CASH AND CASH EQUIVALENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash And Cash Equivalents [Line Items]
Cash	$ 790	$ 210
Short-term deposit	9	13
Cash and cash equivalents, net	799	$ 223	$ 63	$ 150
Terraform Power global [Member] | Brookfield Renewable
Cash And Cash Equivalents [Line Items]
Cash and cash equivalents acquired	$ 611

RESTRICTED CASH (Details)

RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Disclosure Restricted Cash [Abstract]
Operations	$ 195	$ 135
Credit obligations	85	104
Development projects	4	11
Restricted Cash And Cash Equivalents, net	284	250
Less: non-current	103	129
Current	$ 181	$ 121

TRADE RECEIVABLES AND OTHER 110

TRADE RECEIVABLES AND OTHER CURRENT ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure Trade Receivables and Other Current Assets [Abstract]
Trade receivables	$ 360	$ 262
Other short-term receivables	82	103
Prepaids and others	112	89
Trade receivables and other current assets, net	$ 554	$ 454
% of trade AR that is current	99.00%	95.00%
Description of significant payment terms in contracts with customers	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 receivables and the credit worthiness of the counterparties.
Allowance For Doubtful Trade Receivable Accounts	$ 0	$ 0

OTHER LONG-TERM ASSETS (Details

OTHER LONG-TERM ASSETS (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Other Long term assets [Line Items]
Restricted cash	$ 103	$ 129
Unamortized financing fees	5	6
Acqusition Downpayment	46	0
Other	76	41
Other long-term assets, net	230	$ 176
Cost
Other Long term assets [Line Items]
Restricted cash	103
Unamortized financing fees	32
Acqusition Downpayment	46
Other	82
Other long-term assets, net	263
Accumulated Amortization
Other Long term assets [Line Items]
Restricted cash	0
Unamortized financing fees	(27)
Acqusition Downpayment	0
Other	(6)
Other long-term assets, net	$ (33)

ACCOUNTS PAYABLE AND ACCRUED112

ACCOUNTS PAYABLE AND ACCRUED LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Disclosure Accounts Payable and Accured Liabilities [Abstract]
Operating accrued liabilities	$ 271	$ 147
Accounts payable	117	87
Current interest payable	64	68
Deferred consideration	35	55
Acquisition and related provisions	0	54
LP unitholders' distributions, preferred limited partnership unit distributions and preferred dividends payable	29	24
Other	26	32
Total accounts payable and accrued liabilities	$ 542	$ 467

OTHER LONG-TERM LIABILITIES (De

OTHER LONG-TERM LIABILITIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure Other Long Term Liabilities [Line Items]
Acquisition related provisions	$ 80	$ 111
Pension obligations	89	87
Decommissioning retirement obligations	85	47
Contingent consideration	18	16
Commitments for power purchase agreement	13	0
Concession payment liability	9	10
Deferred Revenue	9	7
Other	41	32
Other long-term liabilities, net	$ 344	$ 310
Bottom of range
Disclosure Other Long Term Liabilities [Line Items]
Expected timing of outflows of provision for decommissioning restoration and rehabilitation costs	2,031
Top of range
Disclosure Other Long Term Liabilities [Line Items]
Expected timing of outflows of provision for decommissioning restoration and rehabilitation costs	2,138

COMMITMENTS, CONTINGENCIES A114

COMMITMENTS, CONTINGENCIES AND GUARANTEES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	$ 415
Estimated contingent liabilities for letters of credit	$ 544	$ 549
Brazilian hydroelectric projects
Disclosure of finance lease and operating lease by lessee [line items]
Various agreements can be renewed and are extendable, maximum year	2,091
Development Project Cost	$ 44
Development projects to be operational, Year	2,018
Brookfield Renewable along with institutional investors
Disclosure of finance lease and operating lease by lessee [line items]
Estimated contingent liabilities for letters of credit	$ 76	66
Brookfield Renewable's subsidiaries
Disclosure of finance lease and operating lease by lessee [line items]
Estimated contingent liabilities for letters of credit	468	$ 483
2,018
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	33
2,019
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	32
2,020
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	31
2,021
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	30
2,022
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	27
Thereafter
Disclosure of finance lease and operating lease by lessee [line items]
Minimum lease payments	$ 262

RELATED PARTY (Details - PPA)

RELATED PARTY (Details - PPA) $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2011USD ($)CAD / MWh	Dec. 31, 2017USD ($)$ / MWhCAD / MWhGWh	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Nov. 28, 2011USD ($)
Disclosure of transactions between related parties [line items]
Management Fee Expense		$ (82)	$ (62)	$ (48)
Energy marketing fees		24	23	22
Brookfield Renewable
Disclosure of transactions between related parties [line items]
Management Fee Expense		82	$ 62	$ 48
Management fee fixed component		21
Management fee fixed component quarterly		5
Capitalization for management fees		$ 14,000			$ 8,000
Energy marketing fees	$ 18
Brookfield Renewable | Power purchase agreement GLPL
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI		40.00%
Initial expiry date of power purchase agreements		2,029
Eletricity prices | CAD / MWh	68	82
Brookfield Renewable | Power purchase agreement MPT
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI		20.00%
Initial expiry date of power purchase agreements		2,029
Eletricity prices | CAD / MWh		103
Brookfield Renewable | Power purchase agreement BPUSHA
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 | $ / MWh		75
Brookfield Renewable | Power purchase agreement GLHA
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI		20.00%
Eletricity prices | $ / MWh		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 | CAD / MWh		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 of power purchase agreements		2,029
Eletricity prices | CAD / MWh		68
Brookfield Renewable | Power purchase agreement hydro pontiac two
Disclosure of transactions between related parties [line items]
Annual increment as % of CPI		40.00%
Initial expiry date of power purchase agreements		2,029
Eletricity prices | CAD / MWh		68
Brookfield Renewable | Power purchase agreement wind levelization
Disclosure of transactions between related parties [line items]
Initial expiry date of power purchase agreements		2,019
Expected generation | GWh		506

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details - Income Statement) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues
Power purchase and revenue agreements	$ 601	$ 527	$ 469
Wind levelization agreement	6	8	6
Total related party revenues	607	535	475
Direct operating costs
Energy purchases	(13)	(3)	(5)
Energy marketing fee	(24)	(23)	(22)
Insurace services	(19)	(20)	(30)
Total related party direct operating costs	(56)	(46)	(57)
Management service costs	$ (82)	$ (62)	$ (48)

RELATED PARTY TRANSACTIONS (117

RELATED PARTY TRANSACTIONS (Details - Balance Sheet) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Disclosure of transactions between related parties [line items]
Due from related parties	$ 60	$ 54
Due to related parties	112	76
Brookfield Renewable
Disclosure of transactions between related parties [line items]
Due from related parties	54	47
Due to related parties	48	48
Accrued distributions payable on LP Units and Redeemable/Exchangeable partnership units	32	26
Equity-accounted investments and other
Disclosure of transactions between related parties [line items]
Due from related parties	6	7
Due to related parties	$ 32	$ 2

SUPPLEMENTAL INFORMATION (Detai

SUPPLEMENTAL INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Supplemental cash flow information:
Trade receivables and other current assets	$ (40)	$ 30	$ (72)
Accounts payable and accrued liabilities	32	(160)	2
Other assets and liabilities	(17)	(7)	8
Net change in working capital balances	$ 25	$ 137	$ 62

PENSION AND EMPLOYEE FUTURE 119

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Actuarial Assumptions)	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined benefit pension plans | Bottom of range
Disclosure of actuarial assumptions [line items]
Actuarial assumption of discount rates	2.40%	2.20%	2.90%
Actuarial assumption of expected rates of inflation	1.50%	1.50%	2.00%
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	7.30%	7.30%	4.70%
Actuarial assumption of expected rates of inflation	3.50%	3.50%	2.50%
Actuarial assumption of expected rates of salary increases	4.00%	4.00%	3.00%
Defined benefit nonpension plans | Bottom of range
Disclosure of actuarial assumptions [line items]
Actuarial assumption of discount rates	3.70%	4.10%	4.20%
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%	6.30%
Defined benefit nonpension plans | Top of range
Disclosure of actuarial assumptions [line items]
Actuarial assumption of discount rates	7.10%	7.30%	4.70%
Actuarial assumption of expected rates of salary increases	4.00%	4.00%	3.00%
Actuarial assumption of medical cost trend rates	6.90%	6.90%	7.10%

PENSION AND EMPLOYEE FUTURE 120

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Sensitivity Analysis) $ in Millions	Dec. 31, 2017USD ($)
Fifty basis point increase | Actuarial assumption of discount rates | Defined benefit pension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible increase in actuarial assumption	$ (11)
Fifty basis point increase | Actuarial assumption of discount rates | Defined benefit nonpension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible increase in actuarial assumption	(4)
Fifty basis point increase | Actuarial assumption of expected rates of inflation | Defined benefit pension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible increase in actuarial assumption	4
Fifty basis point increase | Actuarial assumption of medical cost trend rates | Defined benefit nonpension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible increase in actuarial assumption	4
Fifty basis point decrease | Actuarial assumption of discount rates | Defined benefit pension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible decrease in actuarial assumption	13
Fifty basis point decrease | Actuarial assumption of discount rates | Defined benefit nonpension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible decrease in actuarial assumption	5
Fifty basis point decrease | Actuarial assumption of expected rates of inflation | Defined benefit pension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible decrease in actuarial assumption	(4)
Fifty basis point decrease | Actuarial assumption of medical cost trend rates | Defined benefit nonpension plans
Disclosure of sensitivity analysis for actuarial assumptions [line items]
Increase (decrease) in defined benefit obligation due to reasonably possible decrease in actuarial assumption	$ (3)

PENSION AND EMPLOYEE FUTURE 121

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Expenses) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined benefit pension plans
Disclosure Of Defined Benefit Plans Expense [Line Items]
Current service cost	$ 3	$ 3	$ 3
Past service cost (recovery)	(1)	0	1
Interest expense	2	2	1
Administrative expense	1	1	1
Post-employment benefit expense, defined benefit plans	5	6	6
Remeasurement of net defined benefit liability
Return on plan assets	(8)	(2)	(1)
Actuarial changes arising from changes in demographic assumptions	1	(1)	2
Actuarial changes arising from changes in financial assumptions	7	5	(2)
Experience adjustments	0	0	2
Gain (loss) on remeasurement, net defined benefit liability (asset)	0	2	1
Defined benefit expense gain loss recognized, net	5	8	7
Defined benefit nonpension plans
Disclosure Of Defined Benefit Plans Expense [Line Items]
Current service cost	1	1	1
Past service cost (recovery)	0	0	(1)
Interest expense	3	3	2
Administrative expense	0	0	0
Post-employment benefit expense, defined benefit plans	4	4	2
Remeasurement of net defined benefit liability
Return on plan assets	0	0	0
Actuarial changes arising from changes in demographic assumptions	(2)	(1)	(5)
Actuarial changes arising from changes in financial assumptions	3	1	(1)
Experience adjustments	1	0	0
Gain (loss) on remeasurement, net defined benefit liability (asset)	2	0	(6)
Defined benefit expense gain loss recognized, net	$ 6	$ 4	$ (4)

PENSION AND EMPLOYEE FUTURE 122

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Net position) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined benefit pension plans
Disclosure of net defined benefit liability (asset) [line items]
Present value of defined benefit obligation	$ 172	$ 158	$ 124	$ 128
Plan assets, at fair value	(135)	(119)	(103)
Net defined benefit liability (asset)	37	39	21
Defined benefit nonpension plans
Disclosure of net defined benefit liability (asset) [line items]
Present value of defined benefit obligation	57	53	35	$ 43
Plan assets, at fair value	(5)	(5)	0
Net defined benefit liability (asset)	$ 52	$ 48	$ 35

PENSION AND EMPLOYEE FUTURE 123

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Defined benefit obligations) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined benefit pension plans
Disclosure of net defined benefit liability (asset) [line items]
Balance, beginning of year	$ 158	$ 124	$ 128
Current service cost	3	3	3
Past service cost (recovery)	(1)	0	1
Remeasurement of net defined benefit liability
Actuarial changes arising from changes in demographic assumptions	1	(1)	2
Actuarial changes arising from changes in financial assumptions	7	5	(2)
Experience adjustments	0	0	2
Balance, end of year	172	158	124
Defined benefit pension plans | Present value of defined benefit obligation
Disclosure of net defined benefit liability (asset) [line items]
Current service cost	3	3	3
Past service cost (recovery)	(1)	0	1
Interest expense	7	7	5
Remeasurement of net defined benefit liability
Actuarial changes arising from changes in demographic assumptions	1	(1)	2
Actuarial changes arising from changes in financial assumptions	7	5	(2)
Experience adjustments	0	0	2
Benefits paid	(7)	(8)	(5)
Business combination	0	25	0
Increase (decrease) through changes in foreign exchange rates, net defined benefit liability (asset)	4	3	(10)
Defined benefit nonpension plans
Disclosure of net defined benefit liability (asset) [line items]
Balance, beginning of year	53	35	43
Current service cost	1	1	1
Past service cost (recovery)	0	0	(1)
Remeasurement of net defined benefit liability
Actuarial changes arising from changes in demographic assumptions	(2)	(1)	(5)
Actuarial changes arising from changes in financial assumptions	3	1	(1)
Experience adjustments	1	0	0
Balance, end of year	57	53	35
Defined benefit nonpension plans | Present value of defined benefit obligation
Disclosure of net defined benefit liability (asset) [line items]
Current service cost	1	1	1
Past service cost (recovery)	0	0	(1)
Interest expense	3	3	2
Remeasurement of net defined benefit liability
Actuarial changes arising from changes in demographic assumptions	(2)	(1)	(5)
Actuarial changes arising from changes in financial assumptions	3	1	(1)
Experience adjustments	1	0	0
Benefits paid	(2)	(2)	(2)
Business combination	0	14	0
Increase (decrease) through changes in foreign exchange rates, net defined benefit liability (asset)	$ 0	$ 2	$ (2)

PENSION AND EMPLOYEE FUTURE 124

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Plan assets) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined benefit pension plans
Disclosure of plan assets [line items]
Balance, beginning of year	$ (119)	$ (103)
Return on plan assets	(8)	(2)	$ (1)
Balance, end of year	(135)	(119)	(103)
Defined benefit pension plans | Plan assets
Disclosure of plan assets [line items]
Balance, beginning of year	119	103	108
Interest income	5	5	4
Return on plan assets	8	2	1
Employer contribution	5	7	5
Business combination	0	9	0
Benefits paid	(7)	(8)	(5)
Exchange differences	5	1	(10)
Balance, end of year	135	119	103
Defined benefit nonpension plans
Disclosure of plan assets [line items]
Balance, beginning of year	(5)	0
Return on plan assets	0	0	0
Balance, end of year	(5)	(5)	0
Defined benefit nonpension plans | Plan assets
Disclosure of plan assets [line items]
Balance, beginning of year	5	0	0
Interest income	0	0	0
Return on plan assets	0	0	0
Employer contribution	2	3	2
Business combination	0	4	0
Benefits paid	(2)	(2)	(2)
Exchange differences	0	0	0
Balance, end of year	$ 5	$ 5	$ 0

PENSION AND EMPLOYEE FUTURE 125

PENSION AND EMPLOYEE FUTURE BENEFITS (Details - Category of assets)	Dec. 31, 2017	Dec. 31, 2016
Disclosure of fair value of plan assets [abstract]
Cash and cash equivalents	2.00%	5.00%
Equity securities	54.00%	50.00%
Debt securities	44.00%	44.00%
Real estate	0.00%	1.00%
Total	100.00%	100.00%

SUBSIDIARY PUBLIC ISSUERS (Deta

SUBSIDIARY PUBLIC ISSUERS (Details - Balance Sheet) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Nov. 30, 2014
Disclosure of subsidiaries [line items]
Current assets	$ 1,666	$ 907
Current liabilities	2,514	1,733
Equity	14,282	12,672	$ 8,763		$ 8,881
Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Equity	6,298	5,589	2,587	$ 2,062
General partnership interest in a holding subsidiary held by Brookfield
Disclosure of subsidiaries [line items]
Equity	58	55	52	59
Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Equity	2,843	2,680	2,559	2,865
Preferred equity
Disclosure of subsidiaries [line items]
Equity	616	576	$ 610	$ 728
Brookfield Renewable
Disclosure of subsidiaries [line items]
Current assets	32	26
Long-term assets	4,483	3,779
Current liabilities	43	33
Long-term liabilities	0	0
Equity	511	324
BRP Equity
Disclosure of subsidiaries [line items]
Current assets	412	0
Long-term assets	262	620
Current liabilities	7	9
Long-term liabilities	0	0
Equity	0	0
BRP Equity | Preferred equity
Disclosure of subsidiaries [line items]
Equity	616	576
Finco
Disclosure of subsidiaries [line items]
Current assets	1,691	1,581
Long-term assets	0	0
Current liabilities	180	19
Long-term liabilities	1,505	1,556
Equity	0	0
Holding Entities
Disclosure of subsidiaries [line items]
Current assets	525	150
Long-term assets	20,142	18,415
Current liabilities	3,024	2,971
Long-term liabilities	693	738
Equity	516	324
Holding Entities | Participating non-controlling interests - in a holding subsidiary - Redeemable/Exchangeable units held by Brookfield
Disclosure of subsidiaries [line items]
Equity	2,843	2,680
Other Subsidiaries
Disclosure of subsidiaries [line items]
Current assets	2,816	2,092
Long-term assets	29,508	27,250
Current liabilities	3,071	1,644
Long-term liabilities	12,670	12,775
Equity	0	0
Other Subsidiaries | Participating Non-controlling Interests Operating Subsidiaries
Disclosure of subsidiaries [line items]
Equity	6,298	5,589
Consolidating adjustments
Disclosure of subsidiaries [line items]
Current assets	(3,810)	(2,942)
Long-term assets	(25,157)	(23,234)
Current liabilities	(3,811)	(2,943)
Long-term liabilities	(760)	(1,737)
Equity	$ (516)	$ (324)

SUBSIDIARY PUBLIC ISSUERS (D127

SUBSIDIARY PUBLIC ISSUERS (Details - Income Statement) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of subsidiaries [line items]
Revenues	$ 2,625	$ 2,452	$ 1,628
Net (loss) income	51	40	103
Brookfield Renewable
Disclosure of subsidiaries [line items]
Revenues	0	0	0
Net (loss) income	(4)	(20)	2
BRP Equity
Disclosure of subsidiaries [line items]
Revenues	0	0	0
Net (loss) income	10	0	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	1	8
Net (loss) income	(435)	(100)	(42)
Other Subsidiaries
Disclosure of subsidiaries [line items]
Revenues	2,625	2,451	1,620
Net (loss) income	631	558	235
Consolidating adjustments
Disclosure of subsidiaries [line items]
Revenues	0	0	0
Net (loss) income	$ (150)	$ (397)	$ (91)

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) CAD / shares in Units, £ in Millions, COP in Millions, CAD in Millions, BRL in Millions, $ in Millions

Feb. 22, 2018USD ($)

Feb. 15, 2018USD ($)

Jan. 29, 2018BRL

Jan. 19, 2018GBP (£)

Jan. 16, 2018CADCAD / sharesshares

Jan. 16, 2018USD ($)

Jun. 30, 2017

Dec. 31, 2017USD ($)

Dec. 31, 2016USD ($)

Dec. 31, 2015USD ($)

Feb. 28, 2018COP

Feb. 28, 2018USD ($)

Jan. 29, 2018USD ($)

Jan. 19, 2018USD ($)

Disclosure of non-adjusting events after reporting period [line items]

Notional amount

$ 11,842

$ 10,260

Issuance of preferred limited partnership units

187

147

$ 128

Debt

10,090

9,148

Terraform Global

Disclosure of non-adjusting events after reporting period [line items]

Debt

$ 342

Borrowings, maturity

2,031

Credit facilities

Disclosure of non-adjusting events after reporting period [line items]

Notional amount

$ 887

$ 673

Borrowings, interest rate

2.60%

1.90%

Borrowings, maturity

June 30, 2022

Senior Notes

Disclosure of non-adjusting events after reporting period [line items]

Borrowings, interest rate

9.75%

Borrowings, maturity

2,022

Proceeds from refinancing of debt which were used to pay down existing debt

$ 760

Senior Notes | Terraform Global

Disclosure of non-adjusting events after reporting period [line items]

Debt

$ 400

Borrowings, interest rate

6.13%

Borrowings, maturity

2,026

Revolving credit facility

Disclosure of non-adjusting events after reporting period [line items]

Debt

$ 45

Borrowings, maturity

2,021

Bond Refinancing

Disclosure of non-adjusting events after reporting period [line items]

Debt

COP 750

$ 262

2.1 GW pumped storage facility | UNITED KINGDOM | Long-term debt

Disclosure of non-adjusting events after reporting period [line items]

Debt

£ 60

$ 83

Borrowings, maturity

2,021

2.1 GW pumped storage facility | UNITED KINGDOM | Long-term debt | LIBOR

Disclosure of non-adjusting events after reporting period [line items]

Bears interest plus a margin

2.75%

2.75%

2.1 GW pumped storage facility | UNITED KINGDOM | Credit facilities

Disclosure of non-adjusting events after reporting period [line items]

Debt

£ 90

$ 125

19 MW hydroelectric facility | Brazil | Long-term debt

Disclosure of non-adjusting events after reporting period [line items]

Debt

BRL 130

$ 40

19 MW hydroelectric facility | Brazil | Long-term debt | TJLP

Disclosure of non-adjusting events after reporting period [line items]

Bears interest plus a margin

2.15%

2.15%

Borrowings, maturity

2,038

296 MW hydroelectric facility | United States | Green Bond

Disclosure of non-adjusting events after reporting period [line items]

Debt

$ 350

Borrowings, interest rate

4.50%

Borrowings, maturity

2,033

Proceeds from refinancing of debt which were used to pay down existing debt

$ 315

Series 13 Preferred LP Units [Member]

Disclosure of non-adjusting events after reporting period [line items]

Number of shares issued | shares

10,000,000

Par Value Per Share | CAD / shares

CAD 25

Issuance of preferred limited partnership units

CAD 250

$ 201