View Filing Data

$ 292

$ 269

^[1]

$ 824

$ 778

^[1]

Operating Costs and Expenses

^[1]

247

241

^[1]

^[1]

247

246

^[1]

^[1]

Total operating costs and expenses

192

185

^[1]

531

515

^[1]

Operating Income

100

^[1]

293

263

^[1]

Other Income (Expense)

^[1]

^[1]

^[1]

(2)

^[1]

Income Before Income Taxes

(74)

^[1]

(200)

(239)

^[1]

Total other expense, net

(40)

(45)

^[1]

(131)

(175)

^[1]

^[1]

162

^[1]

Less: Pre-acquisition net (loss) income of Drop Down Assets

^[1]

Net Income

^[1]

145

^[1]

(9)

^[1]

Net Income Excluding Pre-acquisition Net Income of Drop Down Assets

^[1]

141

^[1]

Less: Income attributable to noncontrolling interests

^[1]

Net Income Attributable to Clearway Energy, Inc.

$ 21

^[1]

116

^[1]

Earnings Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders

Dividends Per Common Share, Cash Paid

$ 0.320

Common Class C [Member]

Other Income (Expense)

Net Income Attributable to Clearway Energy, Inc.

^[2]

$ 14

$ 19

$ 76

$ 35

Weighted Average Number of Shares Outstanding, Basic

^[2]

Weighted Average Number of Shares Outstanding, Diluted

^[2]

Earnings Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders

^[2]

$ 0.20

$ 0.30

$ 1.14

$ 0.56

Dividends Per Common Share, Cash Paid

^[2]

0.20

0.29

1.10

0.56

$ 0.320

$ 0.28

$ 0.927

$ 0.81

Common Class A [Member]

Other Income (Expense)

Net Income Attributable to Clearway Energy, Inc.

^[2]

$ 7

$ 10

$ 40

$ 19

Weighted Average Number of Shares Outstanding, Basic

^[2]

Weighted Average Number of Shares Outstanding, Diluted

^[2]

Earnings Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders

^[2]

$ 0.20

$ 0.30

$ 1.14

$ 0.56

Dividends Per Common Share, Cash Paid

^[2]

0.20

0.27

1.14

0.56

$ 0.320

$ 0.28

$ 0.927

$ 0.81

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Basic and diluted earnings per share might not recalculate due to presenting values in millions rather than whole dollars.

Consolidated Statements of Comprehensive Loss - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

^[1]

Sep. 30, 2018

Sep. 30, 2017

^[1]

Net income

$ 49

$ 31

$ 145

$ 73

Other Comprehensive Gain, net of tax

Unrealized gain on derivatives, net of income tax expense of $1, $0, $4 and $0

Other comprehensive gain

Comprehensive Income

175

Less: Pre-acquisition net (loss) income of Drop Down Assets

(9)

Less: Comprehensive income attributable to noncontrolling interests

Comprehensive Income Attributable to Clearway Energy, Inc.

$ 24

$ 30

$ 130

$ 55

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Cash and cash equivalents

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-Subparagraph (a)
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1A
-Subparagraph (a)(1)
-URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1B
-Subparagraph (a)
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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-Topic 810
-SubTopic 10
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-Paragraph 1A
-Subparagraph (c)(1)
-URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8736-108599

Reference 6: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
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-Section 55
-Paragraph 4J
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 230
-SubTopic 10
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3000-108585

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 19
-URI http://asc.fasb.org/extlink&oid=108774443&loc=SL4569616-111683

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8933-108599

Reference 10: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=84234705&loc=SL4591552-111686

+ Details

Consolidated Statements of Comprehensive Loss (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Statement of Comprehensive Income [Abstract]
Unrealized gain/loss on derivatives, income tax expense /(benefit)	$ 0	$ 1	$ (3)	$ 0

Consolidated Balance Sheets - USD ($)

Sep. 30, 2018

Dec. 31, 2017

Current Assets

$ 232,000,000

$ 148,000,000

^[1]

Restricted cash

157,000,000

168,000,000

^[1]

Accounts receivable — trade

141,000,000

95,000,000

^[1]

Inventory

39,000,000

^[1]

Notes receivable

3,000,000

13,000,000

^[1]

Prepayments and other current assets

31,000,000

19,000,000

^[1]

Total current assets

603,000,000

482,000,000

^[1]

Property, plant and equipment, net

5,306,000,000

5,410,000,000

^[1]

Other Assets

1,182,000,000

1,178,000,000

^[1]

Intangible assets, net

1,177,000,000

1,228,000,000

^[1]

Derivative instruments

32,000,000

1,000,000

^[1]

Deferred income taxes

108,000,000

128,000,000

^[1]

Other non-current assets

92,000,000

62,000,000

^[1]

Total other assets

2,591,000,000

2,597,000,000

^[1]

Current portion of long-term debt

8,500,000,000

8,489,000,000

^[1]

Current Liabilities

873,000,000

^[2]

339,000,000

^[1]

Accounts payable — trade

90,000,000

46,000,000

^[1]

Accounts payable — affiliate

21,000,000

49,000,000

^[1]

Derivative instruments

5,000,000

18,000,000

^[1]

Accrued expenses and other current liabilities

96,000,000

88,000,000

^[1]

Total current liabilities

1,085,000,000

540,000,000

^[1]

Other Liabilities

Long-term debt

4,928,000,000

5,659,000,000

^[1]

Derivative instruments

9,000,000

31,000,000

^[1]

Other non-current liabilities

103,000,000

100,000,000

^[1]

Total non-current liabilities

5,040,000,000

5,790,000,000

^[1]

Total Liabilities

6,125,000,000

6,330,000,000

^[1]

Commitments and Contingencies

Stockholders' Equity

Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued

^[1]

Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 193,137,143 shares issued and outstanding (Class A 34,586,250, Class B 42,738,750, Class C 73,073,393, Class D 42,738,750) at September 30, 2018 and 184,780,837 shares issued and outstanding (Class A 34,586,250, Class B 42,738,750, Class C 64,717,087, Class D 42,738,750) at December 31, 2017

1,000,000

^[1]

Additional paid-in capital

1,935,000,000

1,843,000,000

^[1]

Retained earnings (accumulated deficit)

13,000,000

(69,000,000)

^[1]

Accumulated other comprehensive loss

(14,000,000)

(28,000,000)

^[1]

Noncontrolling interest

440,000,000

412,000,000

^[1]

Total Stockholders' Equity

2,375,000,000

2,159,000,000

^[1]

Total Liabilities and Stockholders' Equity

$ 8,500,000,000

$ 8,489,000,000

^[1]

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	Current maturities reflect the results of the 2019 Convertible Notes and 2020 Convertible Notes tender offer, as further described below.

Consolidated Balance Sheets (Parenthetical) - USD ($)	Sep. 30, 2018	Dec. 31, 2017
Common Stock, Par or Stated Value Per Share	$ 0.01
Preferred Stock, Par or Stated Value Per Share	$ 0.01
Preferred Stock, Shares Authorized	10,000,000	10,000,000
Preferred Stock, Shares Issued	0	0
Commitments and Contingencies	$ 0	$ 0
Common Class A [Member]
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Stock, Shares Authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	34,586,250	34,586,250
Preferred Stock [Member]
Preferred Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Class B [Member]
Common Stock, Shares Authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	42,738,750	42,738,750
Common Class C [Member]
Common Stock, Shares Authorized	1,000,000,000	1,000,000,000
Common Stock, Shares, Issued	69,081,643	64,717,087
Common Class D [Member]
Common Stock, Shares Authorized	1,000,000,000	1,000,000,000
Common Stock, Shares, Issued	42,738,750	42,738,750

Consolidated Statements Of Cash Flows - USD ($)
$ in Millions

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Cash Flows from Operating Activities

Net income

$ 145

$ 73

^[1]

Adjustments to reconcile net income to net cash provided by operating activities:

Distributions from unconsolidated affiliates

(65)

(63)

^[1]

^[1]

Amortization of financing costs and debt discounts

247

246

^[1]

^[1]

Amortization of intangibles and out-of-market contracts

^[1]

Adjustment for debt extinguishment

(2)

^[1]

Changes in deferred income taxes

^[1]

Derivative interest income

(39)

(5)

^[1]

(Gain) loss on disposal of asset components

(2)

^[1]

Changes in prepaid and accrued liabilities for tolling agreements

^[1]

Changes in other working capital

(44)

(42)

^[1]

Net Cash Provided by Operating Activities

396

373

^[1]

Cash Flows from Investing Activities

Acquisition of businesses, net of cash acquired

Payments for the Drop Down Assets

126

176

^[1]

Capital expenditures

(62)

(102)

^[1]

Cash receipts from notes receivable

^[1]

Return of investment from unconsolidated affiliates

^[1]

Investments in unconsolidated affiliates

(16)

(48)

^[1]

Payments for (Proceeds from) Other Investing Activities

(8)

^[1]

Net Cash Used in Investing Activities

(175)

(283)

^[1]

Cash Flows from Financing Activities

Net contributions from noncontrolling interests

^[1]

Net distributions and return of capital to NRG prior to the acquisition of Drop Down Assets

(26)

^[1]

Net proceeds from the issuance of common stock

151

^[1]

Payments of dividends and distributions

(174)

(149)

^[1]

Payments of debt issuance costs

^[1]

Proceeds from the revolving credit facility

^[1]

Repayments of Lines of Credit

^[1]

Proceeds from the issuance of long-term debt

227

130

^[1]

Payments for long-term debt

(385)

(255)

^[1]

Net Cash Used in Financing Activities

(148)

(265)

^[1]

Net Decrease in Cash, Cash Equivalents and Restricted Cash

(175)

^[1]

Cash, Cash Equivalents and Restricted Cash at Beginning of Period

316

498

^[1]

Cash, Cash Equivalents and Restricted Cash at End of Period

$ 389

$ 323

^[1]

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Nature of Business

9 Months Ended

Sep. 30, 2018

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Business

Clearway Energy, Inc. (formerly NRG Yield, Inc.), together with its consolidated subsidiaries, or the Company, is a publicly-traded energy infrastructure investor in and owner of modern, sustainable and long-term contracted assets across North America. On August 31, 2018, NRG Energy, Inc., or NRG, transferred its full ownership interest in the Company to Clearway Energy Group LLC, or CEG, the holder of NRG's renewable energy development and operations platform, and subsequently sold 100% of its interest in CEG to Global Infrastructure Partners III, or GIP, referred to hereinafter as the NRG Transaction. As a result of the NRG Transaction, GIP indirectly acquired a 45.2% economic interest in Clearway Energy LLC and a 55% voting interest in the Company. GIP is an independent fund manager that invests in infrastructure assets in energy and transport sectors. The Company is sponsored by GIP through GIP's portfolio company, Clearway Energy Group.

The Company’s environmentally-sound asset portfolio includes over 5,272 MW of wind, solar and natural gas-fired power generation facilities, as well as district energy systems. Through this diversified and contracted portfolio, the Company endeavors to provide its investors with stable and growing dividend income. Nearly all of these assets sell substantially all of their output pursuant to long-term offtake agreements with creditworthy counterparties. The weighted average remaining contract duration of these offtake agreements was approximately 15 years as of September 30, 2018 based on CAFD. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,392 net MWt and electric generation capacity of 133 net MW. These thermal infrastructure assets provide steam, hot and/or chilled water, and, in some instances, electricity to commercial businesses, universities, hospitals and governmental units in multiple locations, principally through long-term contracts or pursuant to rates regulated by state utility commissions.

The Company consolidates the results of Clearway Energy LLC through its controlling interest, with CEG's interest shown as noncontrolling interest in the financial statements. The holders of the Company's outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from Clearway Energy LLC through its ownership of Clearway Energy LLC Class B and Class D units.

On September 27, 2018, the Company issued and sold 3,916,449 shares of Class C common stock for net proceeds, after underwriting discounts and expenses, of $75 million. The Company utilized the proceeds of the offering to acquire 3,916,449 Class C units from Clearway Energy LLC and, as a result, the Company currently owns 55.7% of the economic interests of Clearway Energy LLC, with CEG retaining 44.3% of the economic interests of Clearway Energy LLC.

The following table represents the structure of the Company as of September 30, 2018:

As of September 30, 2018, the Company's operating assets are comprised of the following projects:



Projects	Percentage Ownership		Net Capacity (MW)^(a)	Offtake Counterparty	Expiration
Conventional
El Segundo	100	%	550	Southern California Edison	2023
GenConn Devon	50	%	95	Connecticut Light & Power	2040
GenConn Middletown	50	%	95	Connecticut Light & Power	2041
Marsh Landing	100	%	720	Pacific Gas and Electric	2023
Walnut Creek	100	%	485	Southern California Edison	2023
			1,945
Utility Scale Solar
Agua Caliente	16	%	46	Pacific Gas and Electric	2039
Alpine	100	%	66	Pacific Gas and Electric	2033
Avenal	50	%	23	Pacific Gas and Electric	2031
Avra Valley	100	%	26	Tucson Electric Power	2032
Blythe	100	%	21	Southern California Edison	2029
Borrego	100	%	26	San Diego Gas and Electric	2038
Buckthorn Solar	100	%	154	City of Georgetown, TX	2043
CVSR	100	%	250	Pacific Gas and Electric	2038
Desert Sunlight 250	25	%	63	Southern California Edison	2034
Desert Sunlight 300	25	%	75	Pacific Gas and Electric	2039
Kansas South	100	%	20	Pacific Gas and Electric	2033



Projects	Percentage Ownership		Net Capacity (MW)^(a)	Offtake Counterparty	Expiration
Roadrunner	100	%	20	El Paso Electric	2031
TA High Desert	100	%	20	Southern California Edison	2033
Utah Solar Portfolio^{(b) (e)}	50	%	265	PacifiCorp	2036
			1,075
Distributed Solar
Apple I LLC Projects	100	%	9	Various	2032
AZ DG Solar Projects	100	%	5	Various	2025 - 2033
SPP Projects	100	%	25	Various	2026 - 2037
Other DG Projects	100	%	13	Various	2023 - 2039
			52
Wind
Alta I	100	%	150	Southern California Edison	2035
Alta II	100	%	150	Southern California Edison	2035
Alta III	100	%	150	Southern California Edison	2035
Alta IV	100	%	102	Southern California Edison	2035
Alta V	100	%	168	Southern California Edison	2035
Alta X^(b)	100	%	137	Southern California Edison	2038
Alta XI ^(b)	100	%	90	Southern California Edison	2038
Buffalo Bear	100	%	19	Western Farmers Electric Co-operative	2033
Crosswinds ^{(b) (f)}	99	%	21	Corn Belt Power Cooperative	2027
Elbow Creek ^{(b) (f)}	100	%	122	NRG Power Marketing LLC	2022
Elkhorn Ridge ^{(b) (f)}	66.7	%	54	Nebraska Public Power District	2029
Forward ^{(b) (f)}	100	%	29	Constellation NewEnergy, Inc.	2022
Goat Wind ^{(b) (f)}	100	%	150	Dow Pipeline Company	2025
Hardin ^{(b) (f)}	99	%	15	Interstate Power and Light Company	2027
Laredo Ridge	100	%	80	Nebraska Public Power District	2031
Lookout ^{(b) (f)}	100	%	38	Southern Maryland Electric Cooperative	2030
Odin ^{(b) (f)}	99.9	%	20	Missouri River Energy Services	2028
Pinnacle	100	%	55	Maryland Department of General Services and University System of Maryland	2031
San Juan Mesa ^{(b) (f)}	75	%	90	Southwestern Public Service Company	2025
Sleeping Bear ^{(b) (f)}	100	%	95	Public Service Company of Oklahoma	2032
South Trent	100	%	101	AEP Energy Partners	2029
Spanish Fork ^{(b) (f)}	100	%	19	PacifiCorp	2028
Spring Canyon II ^(b)	90.1	%	29	Platte River Power Authority	2039
Spring Canyon III ^(b)	90.1	%	25	Platte River Power Authority	2039
Taloga	100	%	130	Oklahoma Gas & Electric	2031
Wildorado ^{(b) (f)}	100	%	161	Southwestern Public Service Company	2027
			2,200
Thermal
Energy Center Dover LLC	100	%	103	NRG Power Marketing LLC	2018
Thermal generation	100	%	30	Various	Various
			133
Total net generation capacity^(c)			5,405

Thermal equivalent MWt ^(d)	100	%	1,392	Various	Various

^(a)Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.

^(b) Projects are part of tax equity arrangements.

^(c) The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.

^(d) For thermal energy, net capacity represents MWt for steam or chilled water and excludes 134 MWt available under the right-to-use provisions contained in agreements between two of the Company's thermal facilities and certain of its customers.

^(e) Represents interests in Four Brothers Solar, LLC, Granite Mountain Holdings, LLC, and Iron Springs Holdings, LLC, all acquired as part of the March 2017 Drop Down Assets (ownership percentage is based upon cash to be distributed).

^(f) Projects are part of Wind TE Holdco portfolio.

In addition to the facilities owned or leased in the table above, the Company has entered into partnerships to own or purchase solar power generation projects, as well as other ancillary related assets from a related party via intermediate funds. The Company does not consolidate these partnerships and accounts for them as equity method investments. The Company's net interest in these projects is 268 MW based on cash to be distributed pursuant to the partnership agreements as of September 30, 2018. For further discussions, see Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities of this Form 10-Q and Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities to the consolidated financial statements included in the Company's 2017 Form 10-K.

Substantially all of the Company's generation assets are under long-term contractual arrangements for the output or capacity from these assets. The thermal assets are comprised of district energy systems and combined heat and power plants that produce steam, hot water and/or chilled water and, in some instances, electricity at a central plant. Certain district energy systems are subject to rate regulation by state public utility commissions (although they may negotiate certain rates) while the other district energy systems have rates determined by negotiated bilateral contracts.

Recast of the Historical Financial Statements

Prior to the NRG Transaction on August 31, 2018, the Company completed several acquisitions of Drop Down Assets from NRG, which were accounted for as transfer of entities under common control. The accounting guidance for transfers of entities under common control requires retrospective combination of the entities for all periods presented as if the combinations had been in effect from the beginning of the financial statement period or from the date the entities were under common control (if later than the beginning of the financial statement period). The transfers of entities under common control that took place in 2017 and 2018, and affected the historical results in reporting periods in this Form 10-Q as further described in Note 3, Business Acquisitions are: (i) the acquisition of 100% of NRG's interest in Buckthorn Renewables, LLC, or the Buckthorn Solar Drop Down Asset on March 30, 2018, and (ii) in 2017, the acquisition of the November 2017 November Drop Down Assets and August 2017 Drop Down Assets from NRG. The recast of the Company's financial statements for the Buckthorn Solar Drop Down Asset, November 2017 Drop Down Assets and August 2017 Drop Down Assets did not affect the historical net income attributable to Clearway Energy, Inc., weighted average number of shares outstanding, earnings per share or dividends.

Basis of Presentation

The accompanying unaudited interim consolidated financial statements have been prepared in accordance with the SEC’s regulations for interim financial information and with the instructions to Form 10-Q. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. The following notes should be read in conjunction with the accounting policies and other disclosures as set forth in the notes to the consolidated financial statements included in the Company's 2017 Form 10-K. Interim results are not necessarily indicative of results for a full year.

The Company has elected not to push down the effects of the NRG Transaction to its consolidated financial statements and, accordingly, there was no change in basis of presentation related to the NRG transaction.

In the opinion of management, the accompanying unaudited interim consolidated financial statements contain all material adjustments consisting of normal and recurring accruals necessary to present fairly the Company's consolidated financial position as of September 30, 2018, and the results of operations, comprehensive income (loss) and cash flows for the nine months ended September 30, 2018 and 2017.

Transition Services Agreement

As a result of the NRG Transaction, the Company entered into a Transition Services Agreement with NRG, or the NRG TSA, pursuant to which NRG or certain of its affiliates began providing certain services to the Company following the consummation of the NRG Transaction, in exchange for the payment of a fee in respect of such services. The agreement is effective until the earlier of June 30, 2019 or the date that all services are terminated by the Company. The Company may extend the term on a month-by-month basis no later than March 31, 2020 for a fixed monthly fee provided for in the agreement. Expenses related to the NRG TSA are recorded in general and administrative expenses in the consolidated statements of operations.

Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2018

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Use of Estimates

The preparation of consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could be different from these estimates.

Accumulated Depreciation, Accumulated Amortization

The following table presents the accumulated depreciation included in the property, plant and equipment, net, and accumulated amortization included in intangible assets, net, respectively, as of September 30, 2018 and December 31, 2017:



	September 30, 2018		December 31, 2017
	(In millions)
Property, Plant and Equipment Accumulated Depreciation	$	1,507	$	1,285
Intangible Assets Accumulated Amortization	289		237

Noncontrolling Interests

Noncontrolling interests represent the equity associated with the Company's Class B and Class D common shares, the equity associated with CEG's interest in Repowering Partnership LLC, as described in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities, and third-party interests in the net assets under certain tax equity arrangements, which are consolidated by the Company, that have been entered into to finance the cost of wind facilities eligible for tax credits.

The following table reflects the changes in the Company's noncontrolling interest balance for the period from January 1, 2018 through September 30, 2018:



	(In millions)
Balance as of December 31, 2017 as previously reported ^(a)	$	391
Net Assets of Buckthorn Solar Drop Down Asset as of December 31, 2017	21
Balance as of December 31, 2017 as recast	$	412
Capital contributions from tax equity investors, net of distributions ^(b)	108
Comprehensive income	41
Distributions to NRG, net ^(c)	(62		)
Non cash distributions to NRG in connection with the UPMC Thermal Project Asset Acquisition	(12		)
Payment for the Buckthorn Solar Drop Down Asset	(42		)
Net distributions to CEG ^(d)	(9		)
Pre-acquisition net income of the Buckthorn Solar Drop Down Asset	4
Balance as of September 30, 2018	$	440

^(a) As previously reported in the Company's Form 10-K for the year ended December 31, 2017.

^(b) Activity primarily relates to net capital contributions from the TE investor into Buckthorn Holdings LLC in the amount of $99 million, as further described in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities.

^(c)During the period from January 1, 2018 through August 31, 2018.

^(d) Net distributions to CEG primarily consist of distributions on Class B and D units in the amount of $27 million during the period from September 1, 2018 through September 30, 2018, partially offset by a non-cash contribution of $17 million made by CEG in connection with the formation of Repowering Partnership LLC.

Clearway Energy LLC Distributions to NRG and CEG

The following table lists the distributions paid to NRG during the period from January 1, 2018 through August 31, 2018 and to CEG during the period from September 1, 2018 through September 30, 2018 on Clearway Energy LLC's Class B and D units:



	Third Quarter 2018		Second Quarter 2018		First Quarter 2018
Distributions per Class B Unit	$	0.320	$	0.309	$	0.298
Distributions per Class D Unit	$	0.320	$	0.309	$	0.298

On October 31, 2018, Clearway Energy LLC declared a distribution on its Class A, Class B, Class C and Class D units of $0.331 per unit payable on December 17, 2018 to unit holders of record as of December 3, 2018.

Revenue Recognition

Revenue from Contracts with Customers

On January 1, 2018, the Company adopted the guidance in ASC 606, Revenue from Contracts with Customers, or Topic 606, using the modified retrospective method applied to contracts which were not completed as of the adoption date, with no adjustment required to the financial statements upon adoption. Following the adoption of the new standard, the Company’s revenue recognition of its contracts with customers remains materially consistent with its historical practice. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The Company's policies with respect to its various revenue streams are detailed below. In general, the Company applies the invoicing practical expedient to recognize revenue for the revenue streams detailed below, except in circumstances where the invoiced amount does not represent the value transferred to the customer.

Thermal Revenues

Steam and chilled water revenue is recognized as the Company transfers the product to the customer, based on customer usage as determined by meter readings taken at month-end. Some locations read customer meters throughout the month, and recognize estimated revenue for the period between meter read date and month-end. For thermal contracts, the Company’s performance obligation to deliver steam and chilled water is satisfied over time and revenue is recognized based on the invoiced amount. The Thermal Business subsidiaries collect and remit state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes are presented on a net basis in the income statement.

As contracts for steam and chilled water are long-term contracts, the Company has performance obligations under these contracts that have not yet been satisfied. These performance obligations have transaction prices that are both fixed and variable, and that vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the Company cannot accurately estimate the amount of its unsatisfied performance obligations as it will vary based on customer usage, which will depend on factors such as weather and customer activity.

Power Purchase Agreements, or PPAs

The majority of the Company’s revenues are obtained through PPAs or other contractual agreements. Energy, capacity and where applicable, renewable attributes, from the majority of the Company’s renewable energy assets and certain conventional energy plants is sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer. The majority of these PPAs are accounted for as leases. ASC 840 requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. Judgment is required by management in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or capital lease.

Renewable Energy Credits, or RECs

As stated above, renewable energy credits, or RECs, are usually sold through long-term PPAs. Revenue from the sale of self-generated RECs is recognized when the related energy is generated and simultaneously delivered even in cases where there is a certification lag as it has been deemed to be perfunctory.

In a bundled contract to sell energy, capacity and/or self-generated RECs, all performance obligations are deemed to be delivered at the same time and hence, timing of recognition of revenue for all performance obligations is the same and occurs over time. In such cases, it is often unnecessary to allocate transaction price to multiple performance obligations.

Sale of Emission Allowances

The Company records its bank of emission allowances as part of intangible assets. From time to time, management may authorize the transfer of emission allowances in excess of usage from the Company's emission bank to intangible assets held-for-sale for trading purposes. The Company records the sale of emission allowances on a net basis within operating revenue in the Company's consolidated statements of operations.

Disaggregated Revenues

The following tables represent the Company’s disaggregation of revenue from contracts with customers for the three and nine months ended September 30, 2018, along with the reportable segment for each category:



	Three months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Total
Energy revenue^(a)	$	2		$	167		$	50		$	219
Capacity revenue^(a)	86			—			4			90
Contract amortization	(1		)	(15		)	(1		)	(17		)
Total operating revenue	87			152			53			292
Less: Lease revenue	(88		)	(158		)	—			(246		)
Less: Contract amortization	1			15			1			17
Total revenue from contracts with customers	$	—		$	9		$	54		$	63

^(a)The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:



	Conventional Generation		Renewables		Total
Energy Revenue	$	2	$	158	$	160
Capacity Revenue	86		—		86
	88		158		246



	Nine months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Total
Energy revenue^(b)	$	5		$	473		$	139		$	617
Capacity revenue^(b)	250			—			9			259
Contract amortization	(4		)	(46		)	(2		)	(52		)
Total operating revenue	251			427			146			824
Less: Lease revenue	(255		)	(438		)	(1		)	(694		)
Less: Contract amortization	4			46			2			52
Total revenue from contracts with customers	$	—		$	35		$	147		$	182

^(b)The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:



	Conventional Generation		Renewables		Thermal		Total
Energy Revenue	$	5	$	438	$	1	$	444
Capacity Revenue	250		—		—		250
	255		438		1		694

Contract Amortization

Assets and liabilities recognized from power sales agreements assumed through acquisitions related to the sale of electric capacity and energy in future periods for which the fair value has been determined to be significantly less (more) than market are amortized to revenue over the term of each underlying contract based on actual generation and/or contracted volumes or on a straight-line basis, where applicable.

Contract Balances

The following table reflects the contract assets and liabilities included on the Company’s balance sheet as of September 30, 2018:



(In millions)	September 30, 2018
Accounts receivable, net - Contracts with customers	$	35
Accounts receivable, net - Leases	106
Total accounts receivable, net	$	141

Income Taxes

Prior to the NRG Transaction, Clearway Energy, Inc. was included in certain NRG consolidated unitary state tax return filings which was reflected in the Clearway Energy, Inc. state effective tax rate. Following the NRG Transaction, Clearway Energy, Inc. will file under a separate standalone methodology, resulting in a higher state effective tax rate due to a larger percentage of activity allocated to high-tax jurisdictions.

Reclassifications

Certain prior-year amounts have been reclassified for comparative purposes.

Recent Accounting Developments - Not Yet Adopted

ASU 2016-02 — In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), or Topic 842, with the objective to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and to improve financial reporting by expanding the related disclosures. The guidance in Topic 842 provides that a lessee that may have previously accounted for a lease as an operating lease under current GAAP should recognize the assets and liabilities that arise from a lease on the balance sheet. In addition, Topic 842 expands the required quantitative and qualitative disclosures with regards to lease arrangements. The Company will adopt the standard effective January 1, 2019 and expects to elect certain of the practical expedients permitted, including the expedient that permits the Company to retain its existing lease assessment and classification. The Company is currently working through an adoption plan and evaluating the anticipated impact on the Company's results of operations, cash flows and financial position. While the Company is currently evaluating the impact the new guidance will have on its financial position and results of operations, the Company expects to recognize lease liabilities and right of use assets. The extent of the increase to assets and liabilities associated with these amounts remains to be determined pending the Company’s review of its existing lease contracts and service contracts which may contain embedded leases. While this review is still in process, the Company believes the adoption of Topic 842 may be material to its financial statements. The Company is continuing to monitor potential changes to Topic 842 that have been proposed by the FASB and will assess any necessary changes to the implementation as the guidance is updated.

Business Acquisitions Business Acquisitions (Notes)

9 Months Ended

Sep. 30, 2018

Business Acquisitions [Abstract]

Mergers, Acquisitions and Dispositions Disclosures [Text Block]

Business Acquisitions

2018 Acquisitions

UPMC Thermal Project Asset Acquisition — On June 19, 2018, upon reaching substantial completion, the Company acquired from NRG the UPMC Thermal Project for cash consideration of $84 million, subject to working capital adjustments. The Company will pay an additional $5 million to NRG upon final completion of the project pursuant to the EPC agreement. The project adds 73 MWt of thermal equivalent capacity and 7.5 MW of emergency backup thermal capacity to the Company's portfolio. The transaction is reflected in the Company's Thermal segment. The acquisition was funded with the proceeds from the sale of the Series E Notes and Series F Notes, as further described in Note 7, Long-term Debt. The assets transferred to the Company relate to interests under common control by NRG and were recorded at book value in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the purchase price and book value of the assets was recorded as a distribution to NRG and decreased the balance of its noncontrolling interest. The acquisition was determined to be an asset acquisition and not a business combination, therefore no recast of the historical financial information was deemed necessary.

Central CA Fuel Cell 1, LLC — On April 18, 2018, the Company acquired the Central CA Fuel Cell 1, LLC project in Tulare, California from FuelCell Energy Finance, Inc., for cash consideration of $11 million, subject to working capital adjustments. The project adds 2.8 MW of thermal capacity to the Company's portfolio, with a 20-year PPA contract with the City of Tulare. The transaction is reflected in the Company's Thermal segment.

Buckthorn Solar Drop Down Asset — On March 30, 2018, the Company acquired 100% of NRG's interests in Buckthorn Renewables, LLC, which owned a 154 MW construction-stage utility-scale solar generation project located in Texas, or the Buckthorn Solar Drop Down Asset, for cash consideration of approximately $42 million, subject to working capital adjustments. The Company also assumed non-recourse debt of $183 million and non-controlling interest of $19 million (as of acquisition date) attributable to the Class A member, as further described below. The Company converted $132 million of non-recourse debt to a term loan and the remainder of the outstanding debt was paid down with the contribution from the Class A member in the amount of $80 million upon the project reaching substantial completion in May 2018. The purchase price for the Buckthorn Solar Drop Down Asset was funded with cash on hand and borrowings from the Company's revolving credit facility. The assets and liabilities transferred to the Company related to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid and historical value of the entities' equity was recorded as a distribution to NRG and decreased the balance of its noncontrolling interest. Since the transaction constituted a transfer of net assets under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination had been in effect since the inception of common control.

Buckthorn Solar Portfolio, LLC, a wholly owned subsidiary of Buckthorn Renewables, LLC, is the Class B member in a tax equity partnership, Buckthorn Holdings, LLC, the owner of the Buckthorn Solar Drop Down Asset. The Class A member is a tax equity investor, or TE investor, who receives 99% of allocations of taxable income and other items through the six month anniversary of the placed in service date, at which time the allocations change to 67% through the last calendar year before the flip point, and then back to 99% through the flip point (which occurs when the TE Investor obtains a specified return on its initial investment), at which time the allocations to the TE Investor change to 5% for all the periods thereafter. Before the flip point, the TE investor would receive a priority distribution of distributable cash, as defined, plus a percentage of remaining distributable cash after the priority distribution subject to a percentage cap.

The project sells power under a 25-year PPA to the City of Georgetown, Texas, which commenced in July 2018.

The following is a summary of net assets transferred in connection with the acquisition of the Buckthorn Solar Drop Down Asset as of March 31, 2018:



	(In millions)
Assets:
Current assets	$	20
Property, plant and equipment	212
Non-current assets	3
Total assets	235
Liabilities:
Debt (Current and non-current) ^(a)	176
Other current and non-current liabilities	15
Total liabilities	191
Less: noncontrolling interest	19
Net assets acquired	$	25

^(a) Net of $7 million of net debt issuance costs.

2017 Acquisitions

November 2017 Drop Down Assets — On November 1, 2017, the Company acquired a 38 MW solar portfolio primarily comprised of assets from NRG's Solar Power Partners (SPP) funds and other projects developed by NRG, for cash consideration of $74 million, including working capital adjustments, plus assumed non-recourse debt of $26 million.

The purchase price for the November 2017 Drop Down Assets was funded with cash on hand. The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid and historical value of the entities' equity was recorded as a contribution from NRG and increased the balance of its noncontrolling interest. Since the transaction constituted a transfer of net assets under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control.

The following tables present a summary of the Company's historical information combining the financial information for the Buckthorn Solar Drop Down Asset and November 2017 Drop Down Assets transferred in connection with the acquisition:



	Three months ended September 30, 2017
	As Previously Reported ^(a)		Buckthorn Solar Drop Down Asset		November 2017 Drop Down Assets			As Currently Reported
(In millions)
Total operating revenues	$	265	$	—	$	4		$	269
Operating income (loss)	95		—		(11		)	84
Net income (loss)	41		1		(11		)	31
Less: Pre-acquisition net income (loss) of Drop Down Assets	1		1		(11		)	(9		)
Less: Income attributable to noncontrolling interests	11		—		—			11
Net income attributable to Clearway Energy, Inc.	29		—		—			29



	Nine months ended September 30, 2017
	As Previously Reported ^(a)		Buckthorn Solar Drop Down Asset			November 2017 Drop Down Assets			As Currently Reported
(In millions)
Total operating revenues	$	767	$	—		$	11		$	778
Operating income (loss)	271		—			(8		)	263
Net income (loss)	85		(2		)	(10		)	73
Less: Pre-acquisition net income (loss) of Drop Down Assets	18		(2		)	(10		)	6
Less: Income attributable to noncontrolling interests	13		—			—			13
Net income attributable to Clearway Energy, Inc.	54		—			—			54

^(a) As previously reported in the Company's Form 10-Q for the quarter ended September 30, 2017.

August 2017 Drop Down Assets — On August 1, 2017, the Company acquired the remaining 25% interest in Wind TE Holdco, a portfolio of 12 wind projects, from NRG for total cash consideration of $44 million, including working capital adjustments. The purchase agreement also included potential additional payments to NRG dependent upon actual energy prices for merchant periods beginning in 2027, which were estimated and accrued as contingent consideration in the amount of $8 million.

The Company originally acquired 75% of Wind TE Holdco on November 3, 2015, or November 2015 Drop Down Assets, which were consolidated with 25% of the net assets recorded as noncontrolling interest. The assets and liabilities transferred to the Company related to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combination - Related Issues. As the Company had reflected NRG's 25% ownership of Wind TE Holdco in noncontrolling interest, the difference between the cash paid of $44 million, net of the contingent consideration of $8 million, and the historical value of the remaining 25% of $87 million as of July 31, 2017, was recorded as an adjustment to NRG's noncontrolling interest. Since the transaction constituted a transfer of entities under common control, the accounting guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect from the beginning of the financial statement period or from the date the entities were under common control (if later than the beginning of the financial statement period).

March 2017 Drop Down Assets — On March 27, 2017, the Company acquired the following interests from NRG: (i) Agua Caliente Borrower 2 LLC, which owns a 16% interest (approximately 31% of NRG's 51% interest) in the Agua Caliente solar farm, one of the ROFO Assets, representing ownership of approximately 46 net MW of capacity and (ii) NRG's interests in the Utah Solar Portfolio. Agua Caliente is located in Yuma County, AZ and sells power subject to a 25-year PPA with Pacific Gas and Electric, with 22 years remaining on that contract. The seven utility-scale solar farms in the Utah Solar Portfolio are owned by the following entities: Four Brothers Capital, LLC, Iron Springs Capital, LLC, and Granite Mountain Capital, LLC. These utility-scale solar farms achieved commercial operations in 2016, sell power subject to 20-year PPAs with PacifiCorp, a subsidiary of Berkshire Hathaway and are part of a tax equity structure with Dominion Solar Projects III, Inc., or Dominion, through which the Company is entitled to receive 50% of cash to be distributed, as further described below. The Company paid cash consideration of $128 million, which includes $3 million of final net working capital adjustment received by the Company from NRG. The acquisition of the March 2017 Drop Down Assets was funded with cash on hand. The Company recorded the acquired interests as equity method investments. The Company also assumed non-recourse debt of $41 million and $287 million on Agua Caliente Borrower 2 LLC and the Utah Solar Portfolio, respectively, as well as its pro-rata share of non-recourse project-level debt of Agua Caliente Solar LLC, as further described in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities.

The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combination - Related Issues. The difference between the cash paid and the historical value of the entities' equity of $8 million was recorded as an adjustment to NRG's noncontrolling interest. Since the transaction constituted a transfer of entities under common control, the accounting guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect from the beginning of the financial statement period or from the date the entities were under common control (if later than the beginning of the financial statement period).

Variable Interest Entities

9 Months Ended

Sep. 30, 2018

Equity Method Investments and Joint Ventures [Abstract]

Investments Accounted for by the Equity Method and Variable Interest Entities

Entities that are Consolidated

The Company has a controlling financial interest in certain entities which have been identified as VIEs under ASC 810, Consolidations, or ASC 810. These arrangements are primarily related to tax equity arrangements entered into with third parties in order to monetize certain tax credits associated with wind facilities, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the consolidated financial statements included in the Company's 2017 Form 10-K.

Buckthorn Renewables, LLC — As described in Note 3, Business Acquisitions, on March 30, 2018, the Company acquired 100% of NRG’s interest in a 154 MW construction-stage utility-scale solar generation project, Buckthorn Renewables, LLC, which owns 100% interest in Buckthorn Solar Portfolio, LLC, which in turn owns 100% of the Class B membership interests in Buckthorn Holdings, LLC. Buckthorn Holdings, LLC is a tax equity fund, which is a variable interest entity that is consolidated by Buckthorn Solar Portfolio, LLC. The Company is the primary beneficiary, through its position as managing member, and indirectly consolidates Buckthorn Holdings, LLC through Buckthorn Solar Portfolio, LLC. The Class A member is a tax equity investor who made its initial contribution of $19 million on March 30, 2018, which is reflected as noncontrolling interest on the Company’s consolidated balance sheet. The project achieved substantial completion in May 2018, at which time the remaining tax equity contributions of $80 million were funded. The Company utilizes the HLBV method to determine the net income or loss allocated to the tax equity investor noncontrolling interest. The Company recorded $55 million of loss attributable to noncontrolling interest in Buckthorn Renewables, LLC during the period ended September 30, 2018.

Repowering Partnership LLC — On August 30, 2018, Wind TE Holdco, an indirect subsidiary of the Company, entered into a partnership with Clearway Renew LLC, an indirect subsidiary of CEG, in order to facilitate the repowering of the Elbow Creek and Wildorado facilities. Wind TE Holdco contributed its interests in the two facilities and Clearway Renew LLC contributed a turbine supply agreement, including title to certain components that qualify for production tax credits. Clearway Renew LLC paid a $17 million deposit and had a payable for an additional $17 million due to the service provider, which will be funded by an additional contribution from Clearway Renew LLC. Wind TE Holdco is the managing member of Repowering Partnership LLC and consolidates the entity, which is a VIE. Clearway Renew LLC is entitled to allocations of 21% of income, which is reflected in Wind TE Holdco’s noncontrolling interests.

Summarized financial information for the Company's consolidated VIEs consisted of the following as of September 30, 2018:



(In millions)	Wind TE Holdco		Alta Wind TE Holdco		Spring Canyon		Buckthorn Renewables, LLC
Other current and non-current assets	$	192	$	32	$	1	$	21
Property, plant and equipment	354		417		92		225
Intangible assets	2		253		—		—
Total assets	548		702		93		246
Current and non-current liabilities	205		14		5		136
Total liabilities	205		14		5		136
Noncontrolling interest	32		67		50		44
Net assets less noncontrolling interests	$	311	$	621	$	38	$	66

Entities that are not Consolidated

The Company has interests in entities that are considered VIEs under ASC 810, but for which it is not considered the primary beneficiary. The Company accounts for its interests in these entities under the equity method of accounting, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the consolidated financial statements included in the Company's 2017 Form 10-K.

The Company's maximum exposure to loss as of September 30, 2018, is limited to its equity investment in the unconsolidated entities, as further summarized in the table below:



(In millions)	Maximum exposure to loss
Four Brothers Solar, LLC	$	204
GenConn Energy LLC	98
DGPV Holdco 3 LLC	85
DGPV Holdco 1 LLC	78
Granite Mountain Holdings, LLC	74
DGPV Holdco 2 LLC	63
Iron Springs Holdings, LLC	52
RPV Holdco 1 LLC	42

DGPV Holdco 1 LLC — The Company invested $4 million of cash during the nine months ended September 30, 2018 into DGPV Holdco 1 LLC and recorded $1 million due to CEG in accounts payable — affiliate as of September 30, 2018 to be funded as the project milestones are completed. The Company owns approximately 52 MW of distributed solar capacity, based on cash to be distributed, with a weighted average remaining contract life of approximately 17 years as of September 30, 2018.

DGPV Holdco 3 LLC — The Company invested $12 million of cash during the nine months ended September 30, 2018 into DGPV Holdco 3 LLC and recorded $10 million due to CEG in accounts payable — affiliate as of September 30, 2018 to be funded in tranches as the project milestones are completed. The Company owns approximately 59 MW of distributed solar capacity, based on cash to be distributed, with a weighted average remaining contract life of approximately 21 years as of September 30, 2018.

Utah Solar Portfolio — As described in Note 3, Business Acquisitions, on March 27, 2017, as part of the March 2017 Drop Down Assets acquisition, the Company acquired from NRG 100% of the Class A equity interests in the Utah Solar Portfolio, comprised of Four Brothers Solar, LLC, Granite Mountain Holdings, LLC, and Iron Springs Holdings, LLC. The Class B interests of the Utah Solar Portfolio are owned by a tax equity investor, who receives 99% of allocations of taxable income and other items until the flip point, which occurs when the tax equity investor obtains a specified return on its initial investment, at which time the allocations to the tax equity investor change to 50%. The Company generally receives 50% of distributable cash throughout the term of the tax-equity arrangements. The three entities comprising the Utah Solar Portfolio are VIEs. As the Company is not the primary beneficiary, the Company uses the equity method of accounting to account for its interests in the Utah Solar Portfolio. The Company utilizes the HLBV method to determine its share of the income or losses in the investees.

Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2018

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value Accounting under ASC 820

ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:


•	Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date.


•	Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.


•	Level 3—unobservable inputs for the asset or liability only used when there is little, if any, market activity for the asset or liability at the measurement date.

In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement.

For cash and cash equivalents, restricted cash, accounts receivable, accounts payable, accounts payable — affiliates, accrued expenses and other liabilities, the carrying amounts approximate fair value because of the short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy.

The estimated carrying amounts and fair values of the Company’s recorded financial instruments not carried at fair market value are as follows:



	As of September 30, 2018				As of December 31, 2017
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Assets:
Notes receivable	$	3	$	3	$	13	$	13
Liabilities:
Long-term debt, including current portion^(a)	$	5,860	$	5,835	$	6,066	$	6,099

^(a) Excludes deferred financing costs, which are recorded as a reduction to long-term debt on the Company's consolidated balance sheets.

The fair value of the Company's publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of non-publicly traded long-term debt and certain notes receivable of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy. The following table presents the level within the fair value hierarchy for long-term debt, including current portion as of September 30, 2018 and December 31, 2017:



	As of September 30, 2018				As of December 31, 2017
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	1,451	$	4,384	$	1,502	$	4,597

Recurring Fair Value Measurements

The Company records its derivative assets and liabilities at fair value on its consolidated balance sheet. The following table presents assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:



	As of September 30, 2018		As of December 31, 2017
	Fair Value ^(a)		Fair Value ^(a)
(In millions)	Level 2		Level 2
Derivative assets:
Commodity contracts	$	—	$	1
Interest rate contracts	35		1
Total assets	35		2
Derivative liabilities:
Commodity contracts	1		1
Interest rate contracts	13		48
Total liabilities	$	14	$	49

^(a) There were no derivative assets or liabilities classified as Level 1 or Level 3 as of September 30, 2018 and December 31, 2017.

Derivative Fair Value Measurements

The Company's contracts are non-exchange-traded and valued using prices provided by external sources. For the Company’s energy markets, management receives quotes from multiple sources. To the extent that multiple quotes are received, the prices reflect the average of the bid-ask mid-point prices obtained from all sources believed to provide the most liquid market for the commodity.

The fair value of each contract is discounted using a risk free interest rate. In addition, a credit reserve is applied to reflect credit risk, which is, for interest rate swaps, calculated based on credit default swaps using the bilateral method. For commodities, to the extent that the net exposure under a specific master agreement is an asset, the Company uses the counterparty’s default swap rate. If the net exposure under a specific master agreement is a liability, the Company uses a proxy of its own default swap rate. For interest rate swaps and commodities, the credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of September 30, 2018, the credit reserve was $1 million in interest expense. It is possible that future market prices could vary from those used in recording assets and liabilities and such variations could be material.

Concentration of Credit Risk

In addition to the credit risk discussion in Note 2, Summary of Significant Accounting Policies, to the consolidated financial statements included in the Company's 2017 Form 10-K, the following is a discussion of the concentration of credit risk for the Company's financial instruments. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; (ii) monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties.

Counterparty credit exposure includes credit risk exposure under certain long-term agreements, including solar and other PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company estimates the exposure related to these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. Based on these valuation techniques, as of September 30, 2018, credit risk exposure to these counterparties attributable to the Company's ownership interests was approximately $2.5 billion for the next five years. The majority of these power contracts are with utilities with strong credit quality and public utility commission or other regulatory support. However, such regulated utility counterparties can be impacted by changes in government regulations, which the Company is unable to predict.

Derivative Instruments and Hedging Activities Disclosure [Abstract]

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

Accounting for Derivative Instruments and Hedging Activities

9 Months Ended

Sep. 30, 2018

Accounting for Derivative Instruments and Hedging Activities

This footnote should be read in conjunction with the complete description under Note 7, Accounting for Derivative Instruments and Hedging Activities, to the consolidated financial statements included in the Company's 2017 Form 10-K.

Energy-Related Commodities

As of September 30, 2018, the Company had energy-related derivative instruments extending through 2020. At September 30, 2018, these contracts were not designated as cash flow or fair value hedges.

Interest Rate Swaps

As of September 30, 2018, the Company had interest rate derivative instruments on non-recourse debt extending through 2041, a portion of which are designated as cash flow hedges.

Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy of the Company's open derivative transactions broken out by type:



		Total Volume
		September 30, 2018		December 31, 2017
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		2
Interest	Dollars	$	1,909	$	2,050

Fair Value of Derivative Instruments

The following table summarizes the fair value within the derivative instrument valuation on the balance sheet:



	Fair Value
	Derivative Assets ^(a)				Derivative Liabilities
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	2	$	—	$	1	$	4
Interest rate contracts long-term	11		1		4		9
Total Derivatives Designated as Cash Flow Hedges	13		1		5		13
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	1		—		3		13
Interest rate contracts long-term	21		—		5		22
Commodity contracts current	—		1		1		1
Total Derivatives Not Designated as Cash Flow Hedges	22		1		9		36
Total Derivatives	$	35	$	2	$	14	$	49

^(a) Derivative Assets balances classified as current are included within the prepayments and other current assets line item of the consolidated balance sheets as of September 30, 2018 and December 31, 2017.

The Company has elected to present derivative assets and liabilities on the balance sheet on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As of September 30, 2018 and December 31, 2017, there was no outstanding collateral paid or received. The following tables summarize the offsetting of derivatives by the counterparty master agreement level as of September 30, 2018 and December 31, 2017:



As of September 30, 2018	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts^(a):	(In millions)
Derivative liabilities	$	(1	)	$	—		$	(1	)
Total commodity contracts	(1		)	—			(1		)
Interest rate contracts:
Derivative assets	35			(2		)	33
Derivative liabilities	(13		)	2			(11		)
Total interest rate contracts	22			—			22
Total derivative instruments	$	21		$	—		$	21

^(a) There were no commodity contracts classified as derivative assets as of September 30, 2018.



As of December 31, 2017	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	1		$	—		$	1
Derivative liabilities	(1		)	—			(1		)
Total commodity contracts	—			—			—
Interest rate contracts:
Derivative assets	1			(1		)	—
Derivative liabilities	(48		)	1			(47		)
Total interest rate contracts	(47		)	—			(47		)
Total derivative instruments	$	(47	)	$	—		$	(47	)

Accumulated Other Comprehensive Loss

The following table summarizes the effects on the Company’s accumulated OCL balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax:



	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
	(In millions)
Accumulated OCL beginning balance	$	(36	)	$	(70	)	$	(60	)	$	(70	)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	5			4			11			10
Mark-to-market of cash flow hedge accounting contracts	1			3			19			(3		)
Accumulated OCL ending balance, net of income tax benefit of $5 and $16, respectively	(30		)	(63		)	(30		)	(63		)
Accumulated OCL attributable to noncontrolling interests	(16		)	(36		)	(16		)	(36		)
Accumulated OCL attributable to Clearway Energy, Inc.	$	(14	)	$	(27	)	$	(14	)	$	(27	)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $1	$	(8	)				$	(8	)

The Company's regression analysis for Marsh Landing, Walnut Creek and Avra Valley interest rate swaps, while positively correlated, no longer contain matching terms for cash flow hedge accounting. As a result, the Company voluntarily de-designated the Marsh Landing, Walnut Creek and Avra Valley cash flow hedges as of April 28, 2017, and will prospectively mark these derivatives to market through the income statement.

Impact of Derivative Instruments on the Statements of Operations

The Company has interest rate derivative instruments that are not designated as cash flow hedges. The effect of interest rate hedges is recorded to interest expense. For the three months ended September 30, 2018 and 2017, the impact to the consolidated statements of operations was a gain of $9 million and a gain of $7 million, respectively. For the nine months ended September 30, 2018 and 2017, the impact to the consolidated statements of operations was a gain of $40 million and a loss of $2 million, respectively.

A portion of the Company’s derivative commodity contracts relates to its Thermal Business for the purchase of fuel commodities based on the forecasted usage of the thermal district energy centers. Realized gains and losses on these contracts are reflected in the fuel costs that are permitted to be billed to customers through the related customer contracts or tariffs and, accordingly, no gains or losses are reflected in the consolidated statements of operations for these contracts.

See Note 5, Fair Value of Financial Instruments, for a discussion regarding concentration of credit risk.

Long-term Debt

9 Months Ended

Sep. 30, 2018

Debt Disclosure [Abstract]

Changes in Capital Structure [Abstract]

This footnote should be read in conjunction with the complete description under Note 10, Long-term Debt, to the consolidated financial statements included in the Company's 2017 Form 10-K. Long-term debt consisted of the following:



	September 30, 2018			December 31, 2017			September 30, 2018, interest rate % ^(a)	Letters of Credit Outstanding at September 30, 2018
	(In millions, except rates)
2019 Convertible Notes	$	329		$	345		3.500	$	—
2020 Convertible Notes	288			288			3.250	—
2024 Senior Notes	500			500			5.375	—
2026 Senior Notes	350			350			5.000	—
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 ^(b)	—			55			L+1.50	70
Project-level debt:
Agua Caliente Borrower 2, due 2038	39			41			5.430	17
Alpine, due 2022	129			135			L+1.750	16
Alta Wind I - V lease financing arrangements, due 2034 and 2035	901			926			5.696 - 7.015	103
Buckthorn Solar, due 2025	132			169			L+1.750	26
CVSR, due 2037	720			746			2.339 - 3.775	—
CVSR Holdco Notes, due 2037	188			194			4.680	13
El Segundo Energy Center, due 2023	352			400			L+1.75 - L+2.375	138
Energy Center Minneapolis Series C Notes, due 2025	—			83			5.950	—
Energy Center Minneapolis Series D Notes, due 2031	125			125			3.550	—
Energy Center Minneapolis Series E, F, G, H Notes	203			—			various	—
Laredo Ridge, due 2028	91			95			L+1.875	10
Marsh Landing, due 2023	280			318			L+2.125	38
Tapestry, due 2021	154			162			L+1.625	20
Utah Solar Portfolio, due 2022	273			278			various	13
Viento, due 2023	154			163			L+3.00	26
Walnut Creek, due 2023	235			267			L+1.625	82
Other	427			443			various	36
Subtotal project-level debt:	4,403			4,545
Total debt	5,870			6,083
Less current maturities ^(c)	(873		)	(339		)
Less net debt issuance costs	(59		)	(68		)
Less discounts ^(d)	(10		)	(17		)
Total long-term debt	$	4,928		$	5,659

^(a) As of September 30, 2018, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023 where L+ equals 6 month LIBOR plus 3.00% and Utah Solar Portfolio, where L+ equals 1 month LIBOR plus x%.

^(b) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement.

^(c)Current maturities reflect the results of the 2019 Convertible Notes and 2020 Convertible Notes tender offer, as further described below.

^(d)Discounts relate to the 2019 Convertible Notes and 2020 Convertible Notes.

The financing arrangements listed above contain certain covenants, including financial covenants that the Company is required to be in compliance with during the term of the respective arrangement. As of September 30, 2018, the Company was in compliance with all of the required covenants.

The discussion below describes material changes to or additions of long-term debt for the nine months ended September 30, 2018.

Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility

As of September 30, 2018, there were no outstanding borrowings under the revolving credit facility and the Company had $70 million of letters of credit outstanding. On October 9, 2018, the Company terminated certain letters of credit relating to certain project PPAs in exchange for a one-time payment, which reduced the outstanding letters of credit under the revolving credit facility to $45 million as of October 31, 2018.

On April 30, 2018, the Company closed on the refinancing of the revolving credit facility, which extended the maturity of the facility to April 28, 2023, and decreased the Company's overall cost of borrowing from L+2.50% to L+1.75%. The applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement, and was L+1.50% as of September 30, 2018. The facility will continue to be used for general corporate purposes including financing of future acquisitions and posting letters of credit.

Bridge Credit Agreement

On August 31, 2018, the Company entered into a senior unsecured 364-day bridge credit agreement, or the Bridge Credit Agreement, which provides total borrowings of up to a maximum amount of $1.5 billion at a rate per annum equal to LIBOR or a base rate plus an applicable margin equal to 3.00% in the case of LIBOR loans and 2.00% in the case of base rate loans, in each case subject to an additional 0.25% on the 90th day following the effective date of the Bridge Credit Agreement, 0.25% on the 180th day following such effective date and 0.50% on each 90th day thereafter while any loans remain outstanding. The obligation of the lenders to fund loans under the Bridge Credit Agreement will expire on the date that is 110 days after the effective date of the Bridge Credit Agreement. Loans under the Bridge Credit Agreement will mature 364 days after the effective date of the agreement, provided that Clearway Energy Operating LLC may elect in its sole discretion to extend the maturity as provided for in the Bridge Credit Agreement. Borrowings under the Bridge Credit Agreement are guaranteed by Clearway Energy LLC and certain subsidiaries of Clearway Energy Operating LLC. As of September 30, 2018, there were no borrowings under the Bridge Credit Agreement.

In October 2018, the Company reduced the lenders' commitments under the bridge agreement from $1.5 billion to $867.5 million following the offering of the 2025 Senior Notes and the convertible notes tender offer results, each described below. On October 31, 2018, the Company terminated the Bridge Credit Agreement.

2025 Senior Notes

On October 1, 2018, Clearway Energy Operating LLC issued $600 million of senior unsecured notes, or the 2025 Senior Notes. The 2025 Senior Notes bear interest at 5.750% and mature on October 15, 2025. Interest on the 2025 Senior Notes is payable semi-annually on April 15 and October 15 of each year, and interest payments will commence on April 15, 2019. The 2025 Senior Notes are unsecured obligations of Clearway Energy Operating LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC's wholly owned current and future subsidiaries.

2019 Convertible Notes Open Market Repurchases

In August 2018, the Company repurchased an aggregate principal amount of $16 million of the 2019 Convertible Notes in open market transactions. The repurchases were funded through a partial repayment of the intercompany note between Clearway Energy Operating LLC and Clearway Energy, Inc., which was reduced by $16 million.

2019 Convertible Notes and 2020 Convertible Notes Tender Offer

On September 10, 2018, pursuant to the 2019 Convertible Notes and the 2020 Convertible Notes indentures, the Company delivered to the holders of the 2019 Convertible Notes and the 2020 Convertible Notes a fundamental change notice and offer to repurchase any and all of the 2019 Convertible Notes and 2020 Convertible Notes for cash at a price equal to 100% of the principal amount of the Convertible Notes plus any accrued and unpaid interest. The tender offer expired on October 9, 2018. An aggregate principal amount of $109 million of the 2019 Convertible Notes and $243 million of the 2020 Convertible Notes were tendered on or prior to the expiration date and accepted by the Company for purchase. After the expiration of the tender offer, $220 million aggregate principal amount of the 2019 Convertible Notes remain outstanding and $45 million aggregate principal amount of the 2020 Convertible Notes remain outstanding.

Project - level Debt

Energy Center Minneapolis Series E, F, G, H Notes

On June 19, 2018, Energy Center Minneapolis LLC, a subsidiary of the Company, entered into an amended and restated Thermal note purchase and private shelf agreement under which it authorized the issuance of the Series E Notes, Series F Notes, Series G Notes, and Series H Notes, as further described in the table below:



(in millions)	Amount			Interest Rate
Energy Center Minneapolis Series E Notes, due 2033	$	70		4.80	%
Energy Center Minneapolis Series F Notes, due 2033	10			4.60	%
Energy Center Minneapolis Series G Notes, due 2035	83			5.90	%
Energy Center Minneapolis Series H Notes, due 2037	40			4.83	%
Total proceeds	$	203
Repayment of Energy Center Minneapolis Series C Notes, due 2025	(83		)	5.95	%
Net borrowings	$	120

The proceeds from the sale of the Series E Notes and the Series F Notes were utilized to finance the acquisition of the UPMC Thermal Project as described in Note 3, Business Acquisitions. The Series G Notes were used to refinance the Series C Notes as noted above in the table. The Series H Notes were used to make a dividend to Clearway Energy Operating LLC.

The amended and restated Thermal note purchase and private shelf agreement also established a private shelf facility for the future issuance of notes in the amount of $40 million.

Buckthorn Solar Drop Down Asset Debt

As part of the Buckthorn Solar Drop Down Asset acquisition, as further described in Note 3, Business Acquisitions, the Company assumed non-recourse debt of $183 million relating to Buckthorn Solar Portfolio, LLC as of the date of the acquisition, March 30, 2018. The assumed debt consisted of a construction loan and an Investment Tax Credits, or ITC, bridge loan, both at an interest rate of LIBOR plus 1.75%. On May 31, 2018, $132 million of non-recourse debt was converted to a term loan with an expected maturity of May 2025, and the remainder of the non-recourse debt was repaid with the final contribution from the Class A member in the amount of $80 million upon the project reaching substantial completion in May 2018.

Buckthorn Solar entered into a series of fixed for floating interest rate swaps that would fix the interest rate for a minimum of 80% of the outstanding notional amount. All interest rate swap payments by Buckthorn Solar and its counterparties are made quarterly and LIBOR is determined in advance of each interest period.

Earnings Per Share

9 Months Ended

Sep. 30, 2018

Earnings Per Share [Abstract]

Earnings Per Share

Basic earnings per common share is computed by dividing net income by the weighted average number of common shares outstanding. Shares issued during the year are weighted for the portion of the year that they were outstanding. Diluted earnings per share is computed in a manner consistent with that of basic earnings per share while giving effect to all potentially dilutive common shares that were outstanding during the period.

The reconciliation of Clearway Energy, Inc.'s basic and diluted earnings per share is shown in the following tables:



	Three months ended September 30,
	2018				2017
(In millions, except per share data) ^(a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	7	$	14	$	10	$	19
Weighted average number of common shares outstanding — basic	35		69		35		64
Earnings per weighted average common share — basic	$	0.20	$	0.20	$	0.30	$	0.30
Diluted earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	7	$	14	$	13	$	21
Weighted average number of common shares outstanding — diluted	35		69		49		75
Earnings per weighted average common share — diluted	$	0.20	$	0.20	$	0.27	$	0.29



	Nine months ended September 30,
	2018				2017
(In millions, except per share data) ^(a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	40	$	76	$	19	$	35
Weighted average number of common shares outstanding — basic	35		67		35		63
Earnings per weighted average common share — basic	$	1.14	$	1.14	$	0.56	$	0.56
Diluted earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	40	$	85	$	19	$	35
Weighted average number of common shares outstanding — diluted	35		77		35		63
Earnings per weighted average common share — diluted	$	1.14	$	1.10	$	0.56	$	0.56

^(a)Basic and diluted earnings per share might not recalculate due to presenting values in millions rather than whole dollars.

The following table summarizes the Company's outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted earnings per share:



	Three months ended September 30,		Nine months ended September 30,
	2018	2017	2018	2017
	(In millions of shares)
2019 Convertible Notes - Common Class A	—	—	—	15
2020 Convertible Notes - Common Class C	10	—	—	10

Changes in Capital Structure

9 Months Ended

Sep. 30, 2018

Partners' Capital Notes Disclosure [Text Block]

Changes in Capital Structure

Equity Offering

On September 27, 2018, Clearway Energy, Inc. issued and sold 3,916,449 shares of Class C common stock for net proceeds of $75 million. The Company utilized the proceeds of the offering to acquire 3,916,449 Class C units of Clearway Energy LLC and, as a result, the Company currently owns 55.7% of the economic interests of Clearway Energy LLC, with CEG retaining 44.3% of the economic interests of Clearway Energy LLC.

At-the-Market Equity Offering Program, or the ATM Program

Clearway Energy, Inc. is party to an equity distribution agreement with Barclays Capital Inc., Credit Suisse Securities (USA) LLC, J.P. Morgan Securities LLC and RBC Capital Markets, LLC, as sales agents. Pursuant to the terms of the equity distribution agreement, Clearway Energy, Inc. may offer and sell shares of its Class C common stock par value $0.01 per share, from time to time through the sales agents up to an aggregate sales price of $150 million through an at-the-market equity offering program, or the ATM Program. Clearway Energy, Inc. may also sell shares of its Class C common stock to any of the sales agents, as principals for its own account, at a price agreed upon at the time of sale.

The Company sold a total of 4,392,583 shares of Class C common stock for gross proceeds of $77 million during the nine months ended September 30, 2018. The Company incurred commission fees of $762 thousand during the nine months ended September 30, 2018.

As of September 30, 2018, approximately $38 million of Class C common stock remains available for issuance under the ATM Program.

Dividends to Class A and Class C common stockholders

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the nine months ended September 30, 2018:



	Third Quarter 2018		Second Quarter 2018		First Quarter 2018
Dividends per Class A share	$	0.320	$	0.309	$	0.298
Dividends per Class C share	$	0.320	$	0.309	$	0.298

Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.

On October 31, 2018, the Company declared quarterly dividends on its Class A common stock and Class C common stock of $0.331 per share payable on December 17, 2018, to stockholders of record as of December 3, 2018.

The Company also has authorized 10 million shares of preferred stock, par value $0.01 per share. None of the shares of preferred stock have been issued.

Segment Reporting

9 Months Ended

Sep. 30, 2018

Segment Reporting [Abstract]

Segment Reporting

The Company’s segment structure reflects how management currently operates and allocates resources. The Company's businesses are segregated based on conventional power generation, renewable businesses which consist of solar and wind, and the thermal and chilled water business. The Corporate segment reflects the Company's corporate costs. The Company's chief operating decision maker, its Chief Executive Officer, evaluates the performance of its segments based on operational measures including adjusted earnings before interest, taxes, depreciation and amortization, or Adjusted EBITDA, and CAFD, as well as economic gross margin and net income (loss).



	Three months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	87		$	152		$	53		$	—		$	292
Cost of operations	12			39			33			—			84
Depreciation and amortization	26			52			6			—			84
General and administrative	—			—			—			6			6
Acquisition-related transaction and integration costs	—			—			—			17			17
Development costs	—			—			—			1			1
Operating income (loss)	49			61			14			(24		)	100
Equity in earnings of unconsolidated affiliates	3			29			—			—			32
Other income, net	—			1			—			1			2
Interest expense	(13		)	(36		)	(4		)	(21		)	(74		)
Income (loss) before income taxes	39			55			10			(44		)	60
Income tax expense	—			—			—			11			11
Net Income (Loss)	$	39		$	55		$	10		$	(55	)	$	49
Total Assets	$	1,811		$	5,952		$	512		$	225		$	8,500



	Three months ended September 30, 2017
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	88		$	135		$	46		$	—		$	269
Cost of operations	16			34			29			—			79
Depreciation and amortization	27			58			5			—			90
Impairment losses	—			12			—			—			12
General and administrative	—			—			—			4			4
Acquisition-related transaction and integration costs	—			—			—			—			—
Operating income (loss)	45			31			12			(4		)	84
Equity in earnings of unconsolidated affiliates	3			25			—			—			28
Other income, net	1			—			—			—			1
Interest expense	(13		)	(38		)	(2		)	(21		)	(74		)
Income (loss) before income taxes	36			18			10			(25		)	39
Income tax expense	—			—			—			8			8
Net Income (Loss)	$	36		$	18		$	10		$	(33	)	$	31



	Nine months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	251		$	427		$	146		$	—		$	824
Cost of operations	44			106			97			—			247
Depreciation and amortization	76			154			17			—			247
General and administrative	—			—			—			17			17
Acquisition-related transaction and integration costs	—			—			—			19			19
Development costs	—			—			—			1			1
Operating income (loss)	131			167			32			(37		)	293
Equity in earnings of unconsolidated affiliates	8			57			—			—			65
Other income, net	1			2			—			1			4
Interest expense	(33		)	(95		)	(8		)	(64		)	(200		)
Income (loss) before income taxes	107			131			24			(100		)	162
Income tax expense	—			—			—			17			17
Net Income (Loss)	$	107		$	131		$	24		$	(117	)	$	145
Total Assets	$	1,811		$	5,952		$	512		$	225		$	8,500



	Nine months ended September 30, 2017
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	246		$	402		$	130		$	—		$	778
Cost of operations	53			102			86			—			241
Depreciation and amortization	77			154			15			—			246
Impairment losses	—			12			—			—			12
General and administrative	—			—			—			14			14
Acquisition-related transaction and integration costs	—			—			—			2			2
Operating income (loss)	116			134			29			(16		)	263
Equity in earnings of unconsolidated affiliates	9			54			—			—			63
Other income, net	1			1			—			1			3
Loss on debt extinguishment	—			(2		)	—			—			(2		)
Interest expense	(39		)	(130		)	(7		)	(63		)	(239		)
Income (loss) before income taxes	87			57			22			(78		)	88
Income tax expense	—			—			—			15			15
Net Income (Loss)	$	87		$	57		$	22		$	(93	)	$	73

Income Taxes

9 Months Ended

Sep. 30, 2018

Income Tax Disclosure [Abstract]

Income Taxes

Effective Tax Rate

The income tax provision consisted of the following:



	Three months ended September 30,						Nine months ended September 30,
(In millions, except percentages)	2018			2017			2018			2017
Income before income taxes	$	60		$	39		$	162		$	88
Income tax expense	11			8			17			15
Effective income tax rate	18.3		%	20.5		%	10.5		%	17.0		%

For the three and nine months ended September 30, 2018 and 2017, the overall effective tax rate was different than the statutory rate of 21% and 35%, respectively, primarily due to production and investment tax credits generated from certain wind and solar assets, respectively, and earnings allocated to NRG for the period ended August 31, 2018 and CEG for the period from September 1 through September 30, 2018 resulting from their interest in Clearway Energy LLC.

For tax purposes, Clearway Energy LLC is treated as a partnership; therefore, the Company and CEG each record their respective share of taxable income or loss.

Related Party Transactions	9 Months Ended
Related Party Transactions	Sep. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions Disclosure	Related Party Transactions Related Party Transactions with CEG entities Administrative Services Agreements by and between the Company and Clearway Renewable Operation & Maintenance LLC (formerly NRG Renew Operation & Maintenance LLC) Various wholly-owned subsidiaries of the Company in the Renewables segment are party to administrative services agreements with Clearway Renewable Operation & Maintenance LLC (formerly NRG Renew Operation & Maintenance LLC), or RENOM, a wholly-owned subsidiary of CEG, which provides Operation and Maintenance, O&M, services to these subsidiaries. The Company incurred total expenses for these services of $7 million and $22 million for the three and nine months ended September 30, 2018, respectively. The Company incurred total expenses for these services of $5 million and $17 million for the three and nine months ended September 30, 2017, respectively. There was a balance of $5 million due to RENOM as of September 30, 2018 and December 31, 2017. CEG Master Services Agreements Following the consummation of the NRG Transaction, Clearway Energy, Inc. along with Clearway Energy LLC and Clearway Energy Operating LLC entered into Master Services Agreements with CEG, pursuant to which CEG and certain of its affiliates or third party service providers began providing certain services to the Company, and the Company began providing certain services to CEG, in exchange for the payment of fees in respect of such services. Amounts due to CEG or its subsidiaries are recorded as accounts payable - affiliate and amounts due to the Company from CEG and subsidiaries are recorded as accounts receivable - affiliate on the Company's consolidated balance sheet. Related Party Transactions with NRG entities prior to the NRG Transaction The following transactions relate to the period prior to sale of NRG's interest in CEG to GIP on August 31, 2018 and therefore were considered to be related party transactions for all the periods prior to August 31, 2018. Power Purchase Agreements (PPAs) between the Company and NRG Power Marketing Elbow Creek and Dover are parties to PPAs with NRG Power Marketing, a wholly-owned subsidiary of NRG, and generate revenue under the PPAs, which are recorded to operating revenues in the Company's consolidated statements of operations. For the two and eight months ended August 31, 2018, Elbow Creek and Dover, collectively, generated revenues of $2 million and $8 million, respectively. For the three and nine months ended September 30, 2017, Elbow Creek and Dover, collectively, generated revenue of $3 million and $10 million, respectively. Energy Marketing Services Agreement by and between Thermal entities and NRG Power Marketing Energy Center Dover LLC, Energy Center Minneapolis, Energy Center Phoenix LLC, and Energy Center Paxton LLC, or Thermal entities, which are subsidiaries of the Company, are parties to Energy Marketing Services Agreements with NRG Power Marketing. Under the agreements, NRG Power Marketing procures fuel and fuel transportation for the operation of the Thermal entities. For the two and eight months ended August 31, 2018, the Thermal entities purchased $1 million and $7 million, respectively, of natural gas from NRG Power Marketing. For the three and nine months ended September 30, 2017, the Thermal entities purchased $1 million and $7 million, respectively, of natural gas from NRG Power Marketing. O&M Services Agreements by and between the Company's subsidiaries and NRG Certain of the Company's subsidiaries are party to O&M Service Agreements with NRG, pursuant to which NRG subsidiaries provide necessary and appropriate services to operate and maintain the subsidiaries' plant operations, businesses and thermal facilities. NRG is reimbursed for the provided services, as well as for all reasonable and related expenses and expenditures, and payments to third parties for services and materials rendered to or on behalf of the parties to the agreements. NRG is not entitled to any management fee or mark-up under the agreements. The fees incurred under these agreements were $7 million and $27 million for the two and eight months ended August 31, 2018, respectively. The fees incurred under these agreements were $10 million and $29 million for the three and nine months ended September 30, 2017, respectively. O&M Services Agreements by and between GenConn and NRG GenConn incurs fees under two O&M agreements with wholly-owned subsidiaries of NRG. For the two and eight months ended August 31, 2018, the aggregate fees incurred under the agreements were $1 million and $4 million, respectively. For the three and nine months ended September 30, 2017, the aggregate fees incurred under the agreements were $1 million and $4 million, respectively. Administrative Services Agreement by and between Marsh Landing and NRG West Coast LLC Marsh Landing is a party to an administrative services agreement with NRG West Coast LLC, a wholly owned subsidiary of NRG. The Company reimbursed costs under this agreement of $2 million and $11 million for the two and eight months ended August 31, 2018, respectively. The Company reimbursed costs under the agreement of $4 million and $10 million for the three and nine months ended September 30, 2017, respectively. Management Services Agreement by and between the Company and NRG Prior to the NRG Transaction, NRG provided the Company with various operational, management, and administrative services, which include human resources, accounting, tax, legal, information systems, treasury, and risk management, as set forth in the Management Services Agreement. As of August 31, 2018, the base management fee was approximately $9 million per year. Costs incurred under this agreement were $2 million and $7 million for the two and eight months ended August 31, 2018, respectively. Costs incurred under this agreement for the three and nine months ended September 30, 2017 were $2 million and $8 million, respectively. The costs incurred under the Management Services Agreement included certain direct expenses incurred by NRG on behalf of the Company in addition to the base management fee. Subsequent to the NRG Transaction, the Company entered into a Transition Services Agreement with NRG, or the NRG TSA, pursuant to which NRG or certain of its affiliates began providing certain services to the Company following the consummation of the NRG Transaction, in exchange for the payment of a fee in respect of such services. Expenses related to the NRG TSA are recorded in general and administrative expenses in the consolidated statements of operations. On August 31, 2018, in connection with the consummation of the NRG Transaction, the Company entered into a Termination Agreement with Clearway Energy LLC, Clearway Energy Operating LLC and NRG terminating the Management Services Agreement, dated as of July 22, 2013 by and among the Company, Clearway Energy LLC, Clearway Energy Operating LLC and NRG. EPC Agreement by and between ECP and NRG NRG Business Services LLC, a subsidiary of NRG, and Energy Center Pittsburgh LLC, or ECP, a wholly owned subsidiary of the Company, entered into an EPC agreement for the construction of a 73 MWt district energy system for ECP to provide 150 kpph of steam, 6,750 tons of chilled water and 7.5 MW of emergency backup power service to UPMC Mercy. The initial term of the energy services agreement with UPMC Mercy will be for a period of twenty years from the service commencement date. On June 19, 2018, as discussed in Note 3, Business Acquisitions, ECP purchased the UPMC Thermal Project assets from NRG Business Services LLC for cash consideration of $84 million, subject to working capital adjustments. The Company also recorded a payable of approximately $5 million to be paid to NRG upon final completion of the project, which is included in accounts payable as of September 30, 2018.

Contingencies (Notes)	9 Months Ended
Contingencies (Notes)	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Contingencies Disclosure [Text Block]	Contingencies This note should be read in conjunction with the complete description under Note 16, Commitments and Contingencies, to the Company's 2017 Form 10-K. The Company's material legal proceedings are described below. The Company believes that it has valid defenses to these legal proceedings and intends to defend them vigorously. The Company records reserves for estimated losses from contingencies when information available indicates that a loss is probable and the amount of the loss, or range of loss, can be reasonably estimated. As applicable, the Company has established an adequate reserve for the matters discussed below. In addition, legal costs are expensed as incurred. Management assesses such matters based on current information and makes a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought, and the probability of success. The Company is unable to predict the outcome of the legal proceedings below or reasonably estimate the scope or amount of any associated costs and potential liabilities. As additional information becomes available, management adjusts its assessment and estimates of such contingencies accordingly. Because litigation is subject to inherent uncertainties and unfavorable rulings or developments, it is possible that the ultimate resolution of the Company's liabilities and contingencies could be at amounts that are different from its currently recorded reserves and that such difference could be material. In addition to the legal proceedings noted below, the Company and its subsidiaries are party to other litigation or legal proceedings arising in the ordinary course of business. In management's opinion, the disposition of these ordinary course matters will not materially adversely affect the Company's consolidated financial position, results of operations, or cash flows. Braun Litigation — On April 19, 2016, plaintiffs filed a putative class action lawsuit against the Company, the current and former members of its board of directors individually, and other parties in California Superior Court in Kern County, California. Plaintiffs allege various violations of the Securities Act due to the defendants’ alleged failure to disclose material facts related to low wind production prior to the Company's June 22, 2015 Class C common stock offering. Plaintiffs seek compensatory damages, rescission, attorney’s fees and costs. The defendants filed demurrers and a motion challenging jurisdiction on October 18, 2016. On July 30, 2018, the plaintiffs filed an opposition to the defendants’ motion to quash service of the summons and an opposition to the defendants’ demurrer. On October 5, 2018, the defendants filed a reply memorandum of points and authorities in support of defendants' demurrer to the first amended complaint, and a reply memorandum of points and authorities in support of defendants' motion to quash service of summons. On November 1, 2018, the court issued a ruling granting the defendants' motion to quash service of summons.

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2018

Accounting Policies [Abstract]

Revenue Recognition, Policy [Policy Text Block]

Revenue Recognition

Revenue from Contracts with Customers

Thermal Revenues

Power Purchase Agreements, or PPAs

Renewable Energy Credits, or RECs

Sale of Emission Allowances

Disaggregated Revenues



	Three months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Total
Energy revenue^(a)	$	2		$	167		$	50		$	219
Capacity revenue^(a)	86			—			4			90
Contract amortization	(1		)	(15		)	(1		)	(17		)
Total operating revenue	87			152			53			292
Less: Lease revenue	(88		)	(158		)	—			(246		)
Less: Contract amortization	1			15			1			17
Total revenue from contracts with customers	$	—		$	9		$	54		$	63

^(a)The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:



	Conventional Generation		Renewables		Total
Energy Revenue	$	2	$	158	$	160
Capacity Revenue	86		—		86
	88		158		246



	Nine months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Total
Energy revenue^(b)	$	5		$	473		$	139		$	617
Capacity revenue^(b)	250			—			9			259
Contract amortization	(4		)	(46		)	(2		)	(52		)
Total operating revenue	251			427			146			824
Less: Lease revenue	(255		)	(438		)	(1		)	(694		)
Less: Contract amortization	4			46			2			52
Total revenue from contracts with customers	$	—		$	35		$	147		$	182

^(b)The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:



	Conventional Generation		Renewables		Thermal		Total
Energy Revenue	$	5	$	438	$	1	$	444
Capacity Revenue	250		—		—		250
	255		438		1		694

Contract Amortization

Contract Balances

The following table reflects the contract assets and liabilities included on the Company’s balance sheet as of September 30, 2018:



(In millions)	September 30, 2018
Accounts receivable, net - Contracts with customers	$	35
Accounts receivable, net - Leases	106
Total accounts receivable, net	$	141

Income Tax, Policy [Policy Text Block]

Income Taxes

Use of Estimates

Noncontrolling Interest Disclosure [Text Block]

Noncontrolling Interests

The following table reflects the changes in the Company's noncontrolling interest balance for the period from January 1, 2018 through September 30, 2018:



	(In millions)
Balance as of December 31, 2017 as previously reported ^(a)	$	391
Net Assets of Buckthorn Solar Drop Down Asset as of December 31, 2017	21
Balance as of December 31, 2017 as recast	$	412
Capital contributions from tax equity investors, net of distributions ^(b)	108
Comprehensive income	41
Distributions to NRG, net ^(c)	(62		)
Non cash distributions to NRG in connection with the UPMC Thermal Project Asset Acquisition	(12		)
Payment for the Buckthorn Solar Drop Down Asset	(42		)
Net distributions to CEG ^(d)	(9		)
Pre-acquisition net income of the Buckthorn Solar Drop Down Asset	4
Balance as of September 30, 2018	$	440

^(a) As previously reported in the Company's Form 10-K for the year ended December 31, 2017.

^(c)During the period from January 1, 2018 through August 31, 2018.

Clearway Energy LLC Distributions to NRG and CEG



	Third Quarter 2018		Second Quarter 2018		First Quarter 2018
Distributions per Class B Unit	$	0.320	$	0.309	$	0.298
Distributions per Class D Unit	$	0.320	$	0.309	$	0.298

Distributions [Policy Text Block]

LLC Distributions to NRG and CEG



	Third Quarter 2018		Second Quarter 2018		First Quarter 2018
Distributions per Class B Unit	$	0.320	$	0.309	$	0.298
Distributions per Class D Unit	$	0.320	$	0.309	$	0.298

Recent Accounting Developments

Recent Accounting Developments - Not Yet Adopted

Nature of Business Disclosure [Abstract]

Disclosure of accounting policy for income taxes, which may include its accounting policies for recognizing and measuring deferred tax assets and liabilities and related valuation allowances, recognizing investment tax credits, operating loss carryforwards, tax credit carryforwards, and other carryforwards, methodologies for determining its effective income tax rate and the characterization of interest and penalties in the financial statements.

+ References + Details

Segment Reporting Segment Reporting (Policies)	9 Months Ended
Segment Reporting Segment Reporting (Policies)	Sep. 30, 2018
Segment Reporting [Abstract]
Segment Reporting, Policy [Policy Text Block]	The Company’s segment structure reflects how management currently operates and allocates resources. The Company's businesses are segregated based on conventional power generation, renewable businesses which consist of solar and wind, and the thermal and chilled water business. The Corporate segment reflects the Company's corporate costs. The Company's chief operating decision maker, its Chief Executive Officer, evaluates the performance of its segments based on operational measures including adjusted earnings before interest, taxes, depreciation and amortization, or Adjusted EBITDA, and CAFD, as well as economic gross margin and net income (loss).

Nature of Business Nature of Business (Tables)

9 Months Ended

Sep. 30, 2018

Clearway Energy Org Structure

The following table represents the structure of the Company as of September 30, 2018:

Schedule of Ownership

As of September 30, 2018, the Company's operating assets are comprised of the following projects:



Projects	Percentage Ownership		Net Capacity (MW)^(a)	Offtake Counterparty	Expiration
Conventional
El Segundo	100	%	550	Southern California Edison	2023
GenConn Devon	50	%	95	Connecticut Light & Power	2040
GenConn Middletown	50	%	95	Connecticut Light & Power	2041
Marsh Landing	100	%	720	Pacific Gas and Electric	2023
Walnut Creek	100	%	485	Southern California Edison	2023
			1,945
Utility Scale Solar
Agua Caliente	16	%	46	Pacific Gas and Electric	2039
Alpine	100	%	66	Pacific Gas and Electric	2033
Avenal	50	%	23	Pacific Gas and Electric	2031
Avra Valley	100	%	26	Tucson Electric Power	2032
Blythe	100	%	21	Southern California Edison	2029
Borrego	100	%	26	San Diego Gas and Electric	2038
Buckthorn Solar	100	%	154	City of Georgetown, TX	2043
CVSR	100	%	250	Pacific Gas and Electric	2038
Desert Sunlight 250	25	%	63	Southern California Edison	2034
Desert Sunlight 300	25	%	75	Pacific Gas and Electric	2039
Kansas South	100	%	20	Pacific Gas and Electric	2033



Projects	Percentage Ownership		Net Capacity (MW)^(a)	Offtake Counterparty	Expiration
Roadrunner	100	%	20	El Paso Electric	2031
TA High Desert	100	%	20	Southern California Edison	2033
Utah Solar Portfolio^{(b) (e)}	50	%	265	PacifiCorp	2036
			1,075
Distributed Solar
Apple I LLC Projects	100	%	9	Various	2032
AZ DG Solar Projects	100	%	5	Various	2025 - 2033
SPP Projects	100	%	25	Various	2026 - 2037
Other DG Projects	100	%	13	Various	2023 - 2039
			52
Wind
Alta I	100	%	150	Southern California Edison	2035
Alta II	100	%	150	Southern California Edison	2035
Alta III	100	%	150	Southern California Edison	2035
Alta IV	100	%	102	Southern California Edison	2035
Alta V	100	%	168	Southern California Edison	2035
Alta X^(b)	100	%	137	Southern California Edison	2038
Alta XI ^(b)	100	%	90	Southern California Edison	2038
Buffalo Bear	100	%	19	Western Farmers Electric Co-operative	2033
Crosswinds ^{(b) (f)}	99	%	21	Corn Belt Power Cooperative	2027
Elbow Creek ^{(b) (f)}	100	%	122	NRG Power Marketing LLC	2022
Elkhorn Ridge ^{(b) (f)}	66.7	%	54	Nebraska Public Power District	2029
Forward ^{(b) (f)}	100	%	29	Constellation NewEnergy, Inc.	2022
Goat Wind ^{(b) (f)}	100	%	150	Dow Pipeline Company	2025
Hardin ^{(b) (f)}	99	%	15	Interstate Power and Light Company	2027
Laredo Ridge	100	%	80	Nebraska Public Power District	2031
Lookout ^{(b) (f)}	100	%	38	Southern Maryland Electric Cooperative	2030
Odin ^{(b) (f)}	99.9	%	20	Missouri River Energy Services	2028
Pinnacle	100	%	55	Maryland Department of General Services and University System of Maryland	2031
San Juan Mesa ^{(b) (f)}	75	%	90	Southwestern Public Service Company	2025
Sleeping Bear ^{(b) (f)}	100	%	95	Public Service Company of Oklahoma	2032
South Trent	100	%	101	AEP Energy Partners	2029
Spanish Fork ^{(b) (f)}	100	%	19	PacifiCorp	2028
Spring Canyon II ^(b)	90.1	%	29	Platte River Power Authority	2039
Spring Canyon III ^(b)	90.1	%	25	Platte River Power Authority	2039
Taloga	100	%	130	Oklahoma Gas & Electric	2031
Wildorado ^{(b) (f)}	100	%	161	Southwestern Public Service Company	2027
			2,200
Thermal
Energy Center Dover LLC	100	%	103	NRG Power Marketing LLC	2018
Thermal generation	100	%	30	Various	Various
			133
Total net generation capacity^(c)			5,405

Thermal equivalent MWt ^(d)	100	%	1,392	Various	Various

^(a)Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.

^(b) Projects are part of tax equity arrangements.

^(f) Projects are part of Wind TE Holdco portfolio.

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2018

Accounting Policies [Abstract]

Schedule of Accumulated Depreciation and Amortization [Table Text Block]



	September 30, 2018		December 31, 2017
	(In millions)
Property, Plant and Equipment Accumulated Depreciation	$	1,507	$	1,285
Intangible Assets Accumulated Amortization	289		237

Schedule of Change in Noncontrolling Interest [Table Text Block]

The following table reflects the changes in the Company's noncontrolling interest balance for the period from January 1, 2018 through September 30, 2018:



	(In millions)
Balance as of December 31, 2017 as previously reported ^(a)	$	391
Net Assets of Buckthorn Solar Drop Down Asset as of December 31, 2017	21
Balance as of December 31, 2017 as recast	$	412
Capital contributions from tax equity investors, net of distributions ^(b)	108
Comprehensive income	41
Distributions to NRG, net ^(c)	(62		)
Non cash distributions to NRG in connection with the UPMC Thermal Project Asset Acquisition	(12		)
Payment for the Buckthorn Solar Drop Down Asset	(42		)
Net distributions to CEG ^(d)	(9		)
Pre-acquisition net income of the Buckthorn Solar Drop Down Asset	4
Balance as of September 30, 2018	$	440

Distributions Made to Limited Liability Company (LLC) Member, by Distribution [Table Text Block]



	Third Quarter 2018		Second Quarter 2018		First Quarter 2018
Distributions per Class B Unit	$	0.320	$	0.309	$	0.298
Distributions per Class D Unit	$	0.320	$	0.309	$	0.298

Disaggregation of Revenue [Table Text Block]



	Three months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Total
Energy revenue^(a)	$	2		$	167		$	50		$	219
Capacity revenue^(a)	86			—			4			90
Contract amortization	(1		)	(15		)	(1		)	(17		)
Total operating revenue	87			152			53			292
Less: Lease revenue	(88		)	(158		)	—			(246		)
Less: Contract amortization	1			15			1			17
Total revenue from contracts with customers	$	—		$	9		$	54		$	63

^(a)The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:



	Conventional Generation		Renewables		Total
Energy Revenue	$	2	$	158	$	160
Capacity Revenue	86		—		86
	88		158		246



	Nine months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Total
Energy revenue^(b)	$	5		$	473		$	139		$	617
Capacity revenue^(b)	250			—			9			259
Contract amortization	(4		)	(46		)	(2		)	(52		)
Total operating revenue	251			427			146			824
Less: Lease revenue	(255		)	(438		)	(1		)	(694		)
Less: Contract amortization	4			46			2			52
Total revenue from contracts with customers	$	—		$	35		$	147		$	182

^(b)The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:



	Conventional Generation		Renewables		Thermal		Total
Energy Revenue	$	5	$	438	$	1	$	444
Capacity Revenue	250		—		—		250
	255		438		1		694

Contract with Customer, Asset and Liability [Table Text Block]

The following table reflects the contract assets and liabilities included on the Company’s balance sheet as of September 30, 2018:



(In millions)	September 30, 2018
Accounts receivable, net - Contracts with customers	$	35
Accounts receivable, net - Leases	106
Total accounts receivable, net	$	141

Business Acquisitions Business Acquisitions (Tables)

9 Months Ended

Sep. 30, 2018

November 2017 Drop Down Assets and August 2017 Drop Down Assets [Member]

Business Acquisition, Pro Forma Information [Table Text Block]



	Three months ended September 30, 2017
	As Previously Reported ^(a)		Buckthorn Solar Drop Down Asset		November 2017 Drop Down Assets			As Currently Reported
(In millions)
Total operating revenues	$	265	$	—	$	4		$	269
Operating income (loss)	95		—		(11		)	84
Net income (loss)	41		1		(11		)	31
Less: Pre-acquisition net income (loss) of Drop Down Assets	1		1		(11		)	(9		)
Less: Income attributable to noncontrolling interests	11		—		—			11
Net income attributable to Clearway Energy, Inc.	29		—		—			29



	Nine months ended September 30, 2017
	As Previously Reported ^(a)		Buckthorn Solar Drop Down Asset			November 2017 Drop Down Assets			As Currently Reported
(In millions)
Total operating revenues	$	767	$	—		$	11		$	778
Operating income (loss)	271		—			(8		)	263
Net income (loss)	85		(2		)	(10		)	73
Less: Pre-acquisition net income (loss) of Drop Down Assets	18		(2		)	(10		)	6
Less: Income attributable to noncontrolling interests	13		—			—			13
Net income attributable to Clearway Energy, Inc.	54		—			—			54

^(a) As previously reported in the Company's Form 10-Q for the quarter ended September 30, 2017.

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]

The following is a summary of net assets transferred in connection with the acquisition of the Buckthorn Solar Drop Down Asset as of March 31, 2018:



	(In millions)
Assets:
Current assets	$	20
Property, plant and equipment	212
Non-current assets	3
Total assets	235
Liabilities:
Debt (Current and non-current) ^(a)	176
Other current and non-current liabilities	15
Total liabilities	191
Less: noncontrolling interest	19
Net assets acquired	$	25

^(a) Net of $7 million of net debt issuance costs.

Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2018

Entities that are not consolidated [Member]

Schedule of Equity Method Investments [Line Items]

Schedule of Variable Interest Entities [Table Text Block]

The Company's maximum exposure to loss as of September 30, 2018, is limited to its equity investment in the unconsolidated entities, as further summarized in the table below:



(In millions)	Maximum exposure to loss
Four Brothers Solar, LLC	$	204
GenConn Energy LLC	98
DGPV Holdco 3 LLC	85
DGPV Holdco 1 LLC	78
Granite Mountain Holdings, LLC	74
DGPV Holdco 2 LLC	63
Iron Springs Holdings, LLC	52
RPV Holdco 1 LLC	42

Consolidated Entities [Member]

Schedule of Equity Method Investments [Line Items]

Schedule of Variable Interest Entities [Table Text Block]

Summarized financial information for the Company's consolidated VIEs consisted of the following as of September 30, 2018:



(In millions)	Wind TE Holdco		Alta Wind TE Holdco		Spring Canyon		Buckthorn Renewables, LLC
Other current and non-current assets	$	192	$	32	$	1	$	21
Property, plant and equipment	354		417		92		225
Intangible assets	2		253		—		—
Total assets	548		702		93		246
Current and non-current liabilities	205		14		5		136
Total liabilities	205		14		5		136
Noncontrolling interest	32		67		50		44
Net assets less noncontrolling interests	$	311	$	621	$	38	$	66

Estimated carrying values and fair values

Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide.

+ References + Details

Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2018

Fair Value Disclosures [Abstract]

The estimated carrying amounts and fair values of the Company’s recorded financial instruments not carried at fair market value are as follows:



	As of September 30, 2018				As of December 31, 2017
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Assets:
Notes receivable	$	3	$	3	$	13	$	13
Liabilities:
Long-term debt, including current portion^(a)	$	5,860	$	5,835	$	6,066	$	6,099

Fair Value Option, Disclosures [Table Text Block]



	As of September 30, 2018				As of December 31, 2017
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	1,451	$	4,384	$	1,502	$	4,597

Schedule of Fair Value, Assets and Liabilities [Table Text Block]



	As of September 30, 2018		As of December 31, 2017
	Fair Value ^(a)		Fair Value ^(a)
(In millions)	Level 2		Level 2
Derivative assets:
Commodity contracts	$	—	$	1
Interest rate contracts	35		1
Total assets	35		2
Derivative liabilities:
Commodity contracts	1		1
Interest rate contracts	13		48
Total liabilities	$	14	$	49

^(a) There were no derivative assets or liabilities classified as Level 1 or Level 3 as of September 30, 2018 and December 31, 2017.

Accounting for Derivative Instruments and Hedging Activities (Tables)

9 Months Ended

Sep. 30, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Net notional volume buy/(sell) of NRG Yield's open derivative transactions broken out by commodity

The following table summarizes the net notional volume buy of the Company's open derivative transactions broken out by type:



		Total Volume
		September 30, 2018		December 31, 2017
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		2
Interest	Dollars	$	1,909	$	2,050

Fair value within the derivative instrument valuation on the balance sheets

he following table summarizes the fair value within the derivative instrument valuation on the balance sheet:



	Fair Value
	Derivative Assets ^(a)				Derivative Liabilities
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	2	$	—	$	1	$	4
Interest rate contracts long-term	11		1		4		9
Total Derivatives Designated as Cash Flow Hedges	13		1		5		13
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	1		—		3		13
Interest rate contracts long-term	21		—		5		22
Commodity contracts current	—		1		1		1
Total Derivatives Not Designated as Cash Flow Hedges	22		1		9		36
Total Derivatives	$	35	$	2	$	14	$	49

Offsetting of derivatives by counterparty master agreement level and collateral received or paid

The following tables summarize the offsetting of derivatives by the counterparty master agreement level as of September 30, 2018 and December 31, 2017:



As of September 30, 2018	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts^(a):	(In millions)
Derivative liabilities	$	(1	)	$	—		$	(1	)
Total commodity contracts	(1		)	—			(1		)
Interest rate contracts:
Derivative assets	35			(2		)	33
Derivative liabilities	(13		)	2			(11		)
Total interest rate contracts	22			—			22
Total derivative instruments	$	21		$	—		$	21

^(a) There were no commodity contracts classified as derivative assets as of September 30, 2018.



As of December 31, 2017	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	1		$	—		$	1
Derivative liabilities	(1		)	—			(1		)
Total commodity contracts	—			—			—
Interest rate contracts:
Derivative assets	1			(1		)	—
Derivative liabilities	(48		)	1			(47		)
Total interest rate contracts	(47		)	—			(47		)
Total derivative instruments	$	(47	)	$	—		$	(47	)

Effects of NRG Yield's accumulated OCI balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax

The following table summarizes the effects on the Company’s accumulated OCL balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax:



	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
	(In millions)
Accumulated OCL beginning balance	$	(36	)	$	(70	)	$	(60	)	$	(70	)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	5			4			11			10
Mark-to-market of cash flow hedge accounting contracts	1			3			19			(3		)
Accumulated OCL ending balance, net of income tax benefit of $5 and $16, respectively	(30		)	(63		)	(30		)	(63		)
Accumulated OCL attributable to noncontrolling interests	(16		)	(36		)	(16		)	(36		)
Accumulated OCL attributable to Clearway Energy, Inc.	$	(14	)	$	(27	)	$	(14	)	$	(27	)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $1	$	(8	)				$	(8	)

Long-term Debt (Tables)

9 Months Ended

Sep. 30, 2018

Schedule of long-term debt

Long-term debt consisted of the following:



	September 30, 2018			December 31, 2017			September 30, 2018, interest rate % ^(a)	Letters of Credit Outstanding at September 30, 2018
	(In millions, except rates)
2019 Convertible Notes	$	329		$	345		3.500	$	—
2020 Convertible Notes	288			288			3.250	—
2024 Senior Notes	500			500			5.375	—
2026 Senior Notes	350			350			5.000	—
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 ^(b)	—			55			L+1.50	70
Project-level debt:
Agua Caliente Borrower 2, due 2038	39			41			5.430	17
Alpine, due 2022	129			135			L+1.750	16
Alta Wind I - V lease financing arrangements, due 2034 and 2035	901			926			5.696 - 7.015	103
Buckthorn Solar, due 2025	132			169			L+1.750	26
CVSR, due 2037	720			746			2.339 - 3.775	—
CVSR Holdco Notes, due 2037	188			194			4.680	13
El Segundo Energy Center, due 2023	352			400			L+1.75 - L+2.375	138
Energy Center Minneapolis Series C Notes, due 2025	—			83			5.950	—
Energy Center Minneapolis Series D Notes, due 2031	125			125			3.550	—
Energy Center Minneapolis Series E, F, G, H Notes	203			—			various	—
Laredo Ridge, due 2028	91			95			L+1.875	10
Marsh Landing, due 2023	280			318			L+2.125	38
Tapestry, due 2021	154			162			L+1.625	20
Utah Solar Portfolio, due 2022	273			278			various	13
Viento, due 2023	154			163			L+3.00	26
Walnut Creek, due 2023	235			267			L+1.625	82
Other	427			443			various	36
Subtotal project-level debt:	4,403			4,545
Total debt	5,870			6,083
Less current maturities ^(c)	(873		)	(339		)
Less net debt issuance costs	(59		)	(68		)
Less discounts ^(d)	(10		)	(17		)
Total long-term debt	$	4,928		$	5,659

^(a) As of September 30, 2018, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023 where L+ equals 6 month LIBOR plus 3.00% and Utah Solar Portfolio, where L+ equals 1 month LIBOR plus x%.

^(b) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement.

^(c)Current maturities reflect the results of the 2019 Convertible Notes and 2020 Convertible Notes tender offer, as further described below.

^(d)Discounts relate to the 2019 Convertible Notes and 2020 Convertible Notes.

Energy Center Minneapolis Series E, F, G, H Notes [Member]

Schedule of Long-term Debt Instruments [Table Text Block]



(in millions)	Amount			Interest Rate
Energy Center Minneapolis Series E Notes, due 2033	$	70		4.80	%
Energy Center Minneapolis Series F Notes, due 2033	10			4.60	%
Energy Center Minneapolis Series G Notes, due 2035	83			5.90	%
Energy Center Minneapolis Series H Notes, due 2037	40			4.83	%
Total proceeds	$	203
Repayment of Energy Center Minneapolis Series C Notes, due 2025	(83		)	5.95	%
Net borrowings	$	120

Schedule of Earnings Per Share, Basic and Diluted

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=114775744&loc=d3e28541-108399

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21506-112644

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=114775744&loc=d3e28551-108399

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21521-112644

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21538-112644

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=75038535&loc=d3e64711-112823

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=114775985&loc=d3e28878-108400

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21475-112644

+ Details

Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2018

Earnings Per Share [Abstract]

The reconciliation of Clearway Energy, Inc.'s basic and diluted earnings per share is shown in the following tables:



	Three months ended September 30,
	2018				2017
(In millions, except per share data) ^(a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	7	$	14	$	10	$	19
Weighted average number of common shares outstanding — basic	35		69		35		64
Earnings per weighted average common share — basic	$	0.20	$	0.20	$	0.30	$	0.30
Diluted earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	7	$	14	$	13	$	21
Weighted average number of common shares outstanding — diluted	35		69		49		75
Earnings per weighted average common share — diluted	$	0.20	$	0.20	$	0.27	$	0.29



	Nine months ended September 30,
	2018				2017
(In millions, except per share data) ^(a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	40	$	76	$	19	$	35
Weighted average number of common shares outstanding — basic	35		67		35		63
Earnings per weighted average common share — basic	$	1.14	$	1.14	$	0.56	$	0.56
Diluted earnings per share attributable to Clearway Energy, Inc. common stockholders
Net income attributable to Clearway Energy, Inc.	$	40	$	85	$	19	$	35
Weighted average number of common shares outstanding — diluted	35		77		35		63
Earnings per weighted average common share — diluted	$	1.14	$	1.10	$	0.56	$	0.56

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]

The following table summarizes the Company's outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted earnings per share:



	Three months ended September 30,		Nine months ended September 30,
	2018	2017	2018	2017
	(In millions of shares)
2019 Convertible Notes - Common Class A	—	—	—	15
2020 Convertible Notes - Common Class C	10	—	—	10

Changes in Capital Structure Stockholders' Equity (Tables)

9 Months Ended

Sep. 30, 2018

Changes in Capital Structure [Abstract]

Dividends Declared [Table Text Block]

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the nine months ended September 30, 2018:



	Third Quarter 2018		Second Quarter 2018		First Quarter 2018
Dividends per Class A share	$	0.320	$	0.309	$	0.298
Dividends per Class C share	$	0.320	$	0.309	$	0.298

Segment Reporting (Tables)

9 Months Ended

Sep. 30, 2018

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment



	Three months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	87		$	152		$	53		$	—		$	292
Cost of operations	12			39			33			—			84
Depreciation and amortization	26			52			6			—			84
General and administrative	—			—			—			6			6
Acquisition-related transaction and integration costs	—			—			—			17			17
Development costs	—			—			—			1			1
Operating income (loss)	49			61			14			(24		)	100
Equity in earnings of unconsolidated affiliates	3			29			—			—			32
Other income, net	—			1			—			1			2
Interest expense	(13		)	(36		)	(4		)	(21		)	(74		)
Income (loss) before income taxes	39			55			10			(44		)	60
Income tax expense	—			—			—			11			11
Net Income (Loss)	$	39		$	55		$	10		$	(55	)	$	49
Total Assets	$	1,811		$	5,952		$	512		$	225		$	8,500



	Three months ended September 30, 2017
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	88		$	135		$	46		$	—		$	269
Cost of operations	16			34			29			—			79
Depreciation and amortization	27			58			5			—			90
Impairment losses	—			12			—			—			12
General and administrative	—			—			—			4			4
Acquisition-related transaction and integration costs	—			—			—			—			—
Operating income (loss)	45			31			12			(4		)	84
Equity in earnings of unconsolidated affiliates	3			25			—			—			28
Other income, net	1			—			—			—			1
Interest expense	(13		)	(38		)	(2		)	(21		)	(74		)
Income (loss) before income taxes	36			18			10			(25		)	39
Income tax expense	—			—			—			8			8
Net Income (Loss)	$	36		$	18		$	10		$	(33	)	$	31



	Nine months ended September 30, 2018
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	251		$	427		$	146		$	—		$	824
Cost of operations	44			106			97			—			247
Depreciation and amortization	76			154			17			—			247
General and administrative	—			—			—			17			17
Acquisition-related transaction and integration costs	—			—			—			19			19
Development costs	—			—			—			1			1
Operating income (loss)	131			167			32			(37		)	293
Equity in earnings of unconsolidated affiliates	8			57			—			—			65
Other income, net	1			2			—			1			4
Interest expense	(33		)	(95		)	(8		)	(64		)	(200		)
Income (loss) before income taxes	107			131			24			(100		)	162
Income tax expense	—			—			—			17			17
Net Income (Loss)	$	107		$	131		$	24		$	(117	)	$	145
Total Assets	$	1,811		$	5,952		$	512		$	225		$	8,500



	Nine months ended September 30, 2017
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	246		$	402		$	130		$	—		$	778
Cost of operations	53			102			86			—			241
Depreciation and amortization	77			154			15			—			246
Impairment losses	—			12			—			—			12
General and administrative	—			—			—			14			14
Acquisition-related transaction and integration costs	—			—			—			2			2
Operating income (loss)	116			134			29			(16		)	263
Equity in earnings of unconsolidated affiliates	9			54			—			—			63
Other income, net	1			1			—			1			3
Loss on debt extinguishment	—			(2		)	—			—			(2		)
Interest expense	(39		)	(130		)	(7		)	(63		)	(239		)
Income (loss) before income taxes	87			57			22			(78		)	88
Income tax expense	—			—			—			15			15
Net Income (Loss)	$	87		$	57		$	22		$	(93	)	$	73

Income Taxes (Tables)

9 Months Ended

Sep. 30, 2018

Income Tax Disclosure [Abstract]

Reconciliation of the U.S. federal statutory rate to the Company's effective rate

The income tax provision consisted of the following:



	Three months ended September 30,						Nine months ended September 30,
(In millions, except percentages)	2018			2017			2018			2017
Income before income taxes	$	60		$	39		$	162		$	88
Income tax expense	11			8			17			15
Effective income tax rate	18.3		%	20.5		%	10.5		%	17.0		%

Nature of Business (Details)
$ in Millions

9 Months Ended

Sep. 27, 2018

USD ($)

Mar. 31, 2018

USD ($)

Aug. 02, 2017

USD ($)

Mar. 27, 2017

USD ($)

Sep. 30, 2018

USD ($)

Mar. 30, 2018

USD ($)

Dec. 31, 2017

USD ($)

Weighted Average Remaining PPA Term

15 years

Sale of Stock, Number of Shares Issued in Transaction | shares

^[1],[2]

5,405

3,916,449

4,392,583

Proceeds from Issuance or Sale of Equity | $

$ 75

Power Generation Capacity, Megawatts, including portion attributable to noncontrolling interest

5,411

Megawatts Thermal Equivalent, Available Under right-to-use Provisions

134

Long-term Debt | $

$ 5,870

$ 6,083

Conventional Generation, Utility-Scale Solar, Distributed Solar, and Wind [Member]

Conventional Generation [Member]

^[1]

5,272

^[1]

1,945

Utility-Scale Solar

Distributed Solar [Member]

^[1]

1,075

Wind Farms [Member]

^[1]

2,200

100.00%

Steam and Chilled Water Capacity, Megawatts Thermal Equivalent

^[1]

133

^[1],[3]

1,392

Clearway Energy, Inc. [Member]

Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Voting Interest

45.00%

Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest

55.70%

Clearway Energy LLC [Member] | CEG [Member]

Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Voting Interest

55.00%

Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest

44.30%

GenConn Middletown | Conventional Generation [Member]

50.00%

GenConn Devon [Member] | Conventional Generation [Member]

^[1]

50.00%

Marsh Landing | Conventional Generation [Member]

^[1]

100.00%

El Segundo [Member] | Conventional Generation [Member]

^[1]

720

100.00%

Walnut Creek [Member] | Conventional Generation [Member]

^[1]

550

100.00%

Agua Caliente [Member] | Utility-Scale Solar

^[1]

485

16.00%

Alpine [Member] | Utility-Scale Solar

^[1]

100.00%

Avenal [Member] | Utility-Scale Solar

^[1]

50.00%

Avra Valley | Utility-Scale Solar

^[1]

100.00%

NRG Solar Blythe LLC [Member] | Utility-Scale Solar

^[1]

100.00%

Borrego [Member] | Utility-Scale Solar

^[1]

100.00%

CVSR [Member] | Utility-Scale Solar

^[1]

100.00%

Desert Sunlight [Member] | Utility-Scale Solar

^[1]

250

Kansas South [Member] | Utility-Scale Solar

25.00%

100.00%

Roadrunner | Utility-Scale Solar

^[1]

100.00%

TA - High Desert LLC [Member] | Utility-Scale Solar

^[1]

100.00%

Utah Portfolio [Member] | Utility-Scale Solar

^[1]

50.00%

AZ DG Solar Projects [Member] | Distributed Solar [Member]

^[1],[4],[5]

265

100.00%

PFMG DG Solar Projects [Member] | Distributed Solar [Member]

100.00%

Alta I [Member] | Wind Farms [Member]

100.00%

Alta II [Member] | Wind Farms [Member]

^[1]

150

100.00%

Alta III [Member] | Wind Farms [Member]

^[1]

150

100.00%

Alta IV [Member] | Wind Farms [Member]

^[1]

150

100.00%

Alta V [Member] | Wind Farms [Member]

^[1]

102

100.00%

Alta X [Member] | Wind Farms [Member]

^[1]

168

100.00%

Alta XI [Member] | Wind Farms [Member]

^[1],[4]

137

100.00%

South Trent | Wind Farms [Member]

^[1],[4]

100.00%

Spanish Fork [Member] | Wind Farms [Member]

^[1]

101

100.00%

Spring Canyon II [Member] | Wind Farms [Member]

^[1],[4],[6]

90.10%

Laredo Ridge [Member] | Wind Farms [Member]

^[1],[4]

100.00%

Lookout [Member] | Wind Farms [Member]

^[1]

100.00%

Odin Wind Farm [Member] | Wind Farms [Member]

^[1],[4],[6]

99.90%

Taloga [Member] | Wind Farms [Member]

^[1],[4],[6]

100.00%

Wildorado [Member] | Wind Farms [Member]

^[1]

130

100.00%

Pinnacle [Member] | Wind Farms [Member]

^[1],[4]

161

100.00%

San Juan Mesa Wind Project, LLC [Member] | Wind Farms [Member]

^[1]

75.00%

Sleeping Bear [Member] | Wind Farms [Member]

^[1],[4],[6]

100.00%

Buffalo Bear [Member] | Wind Farms [Member]

^[1],[4],[6]

100.00%

Crosswinds [Member] | Wind Farms [Member]

^[1]

99.00%

Elbow Creek [Member] | Wind Farms [Member]

^[1],[4],[6]

100.00%

Elkhorn Ridge Wind, LLC [Member] | Wind Farms [Member]

^[1],[4],[6]

122

66.70%

Forward [Member] | Wind Farms [Member]

^[1],[4],[6]

100.00%

Goat Wind [Member] | Wind Farms [Member]

^[1],[4],[6]

100.00%

Hardin [Member] | Wind Farms [Member]

^[1],[4],[6]

150

99.00%

Spring Canyon [Member] | Wind Farms [Member]

^[1],[4],[6]

Power Generation Capacity, Megawatts attributed to noncontrolling interest

Spring Canyon III [Member] | Wind Farms [Member]

90.10%

Thermal [Member] | Thermal [Member]

^[1],[4]

100.00%

SPP Projects [Member] | Distributed Solar [Member]

^[1]

100.00%

Other DG Assets [Member] | Distributed Solar [Member]

100.00%

Buckthorn Solar [Member] | Utility-Scale Solar

100.00%

Energy Center Dover [Member] | Thermal [Member]

^[1]

154

100.00%

^[1]

103

Business Acquisitions, Purchase Price | $

154

$ 42

Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value | $

$ 19

Business Acquisitions, Purchase Price | $

$ 44

Southern California Edison [Member] | Desert Sunlight [Member] | Utility-Scale Solar

Pacific Gas and Electric [Member] | Desert Sunlight [Member] | Utility-Scale Solar

^[1]

Unconsolidated Solar Partnerships [Member]

^[1]

March 2017 Drop Down Assets [Member]

268

Business Acquisitions, Purchase Price | $

$ 128

Agua Caliente Borrower 2 [Member]

16.00%

Summary of Significant Accounting Policies [Line Items]

[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[2]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.
[3]	For thermal energy, net capacity represents MWt for steam or chilled water and excludes 134 MWt available under the right-to-use provisions contained in agreements between two of the Company's thermal facilities and certain of its customers.
[4]	Projects are part of tax equity arrangements
[5]	Represents interests in Four Brothers Solar, LLC, Granite Mountain Holdings, LLC, and Iron Springs Holdings, LLC, all acquired as part of the March 2017 Drop Down Assets (ownership percentage is based upon cash to be distributed).
[6]	Projects are part of Wind TE Holdco portfolio.

Summary of Significant Accounting Policies (Details) - USD ($)
$ / shares in Units, $ in Millions

1 Months Ended

3 Months Ended

8 Months Ended

9 Months Ended

May 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Sep. 30, 2017

Aug. 31, 2018

Sep. 30, 2018

Sep. 30, 2017

Dec. 31, 2017

Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment

$ 1,507

$ 1,285

Finite-Lived Intangible Assets, Accumulated Amortization

289

237

Stockholders' Equity Attributable to Noncontrolling Interest

(440)

(412)

^[1]

Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest

2,375

2,159

^[1]

Pre-acquisition net income of the Buckthorn Solar Drop Down Asset

$ (9)

^[1]

$ 6

^[1]

Comprehensive income

^[1]

$ 41

^[1]

Dividends Payable, Date Declared

Oct. 31, 2018

Common Stock, Dividends, Per Share, Declared

$ 0.331

Dividends Payable, Date to be Paid

Dec. 17, 2018

Dividends Payable, Date of Record

Dec. 03, 2018

Revenue from Contract with Customer, Excluding Assessed Tax

$ 182

Operating Leases, Income Statement, Contingent Revenue

292

269

^[1]

824

778

^[1]

(246)

(694)

Accounts Receivable, Net

141

$ 141

141

UPMC Thermal [Member]

Summary of Significant Accounting Policies [Line Items]

Payment of capital distributions and returns of capital, net of capital distributions, non-cash

(12)

Summary of Significant Accounting Policies [Line Items]

Payment for the Buckthorn Solar Drop Down Asset

(42)

Pre-acquisition net income of the Buckthorn Solar Drop Down Asset

(2)

Financial Institutions [Member]

Summary of Significant Accounting Policies [Line Items]

Capital contributions from tax equity investors, net of distributions (b)

^[2]

108

Common Class B [Member]

Summary of Significant Accounting Policies [Line Items]

Distribution Made to Limited Liability Company (LLC) Member, Distributions Paid, Per Unit

$ 0.320

$ 0.309

$ 0.298

Common Class D [Member]

Summary of Significant Accounting Policies [Line Items]

Distribution Made to Limited Liability Company (LLC) Member, Distributions Paid, Per Unit

$ 0.320

$ 0.309

$ 0.298

Summary of Significant Accounting Policies [Line Items]

Stockholders' Equity Attributable to Noncontrolling Interest

(21)

Capital contributions from tax equity investors, net of distributions (b)

$ 80

Customer Contracts [Member]

Summary of Significant Accounting Policies [Line Items]

Accounts Receivable, Net

$ 35

Lease Agreements [Member]

Summary of Significant Accounting Policies [Line Items]

Accounts Receivable, Net

106

Conventional Generation [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

Operating Leases, Income Statement, Contingent Revenue

251

246

(88)

(255)

Renewables [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

Operating Leases, Income Statement, Contingent Revenue

152

135

427

402

(158)

(438)

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

147

Operating Leases, Income Statement, Contingent Revenue

146

130

(1)

Energy Revenue [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

219

^[3]

617

^[4]

Operating Leases, Income Statement, Contingent Revenue

(160)

(444)

Energy Revenue [Member] | Conventional Generation [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

^[4]

Operating Leases, Income Statement, Contingent Revenue

(2)

(5)

Energy Revenue [Member] | Renewables [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

167

^[3]

473

^[4]

Operating Leases, Income Statement, Contingent Revenue

(158)

(438)

Energy Revenue [Member] | Thermal [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

139

^[4]

Operating Leases, Income Statement, Contingent Revenue

(1)

Capacity Revenue [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

259

^[4]

Operating Leases, Income Statement, Contingent Revenue

(86)

(250)

Capacity Revenue [Member] | Conventional Generation [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

250

^[4]

Operating Leases, Income Statement, Contingent Revenue

(86)

(250)

Capacity Revenue [Member] | Renewables [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

^[3]

^[4]

Operating Leases, Income Statement, Contingent Revenue

Capacity Revenue [Member] | Thermal [Member]

Summary of Significant Accounting Policies [Line Items]

Revenue from Contract with Customer, Excluding Assessed Tax

$ 4

^[3]

^[4]

Operating Leases, Income Statement, Contingent Revenue

$ 0

Previously Reported [Member]

Summary of Significant Accounting Policies [Line Items]

Stockholders' Equity Attributable to Noncontrolling Interest

^[5]

$ (391)

Pre-acquisition net income of the Buckthorn Solar Drop Down Asset

^[6]

Summary of Significant Accounting Policies [Line Items]

^[6]

$ 265

$ 767

NRG [Member]

Distributions to NRG, net (c)

^[7]

$ (62)

CEG [Member]

Summary of Significant Accounting Policies [Line Items]

Dividends, Common Stock, Stock

Payment of capital distributions and returns of capital, net of capital distributions, non-cash

Distributions to NRG, net (c)

^[8]

$ (9)

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	Activity primarily relates to net capital contributions from the TE investor into Buckthorn Holdings LLC in the amount of $99 million, as further described in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities.
[3]	The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840: Conventional Generation Renewables TotalEnergy Revenue $2 $158 $160Capacity Revenue 86 — 86 88 158 246
[4]	The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 840:
[5]	As previously reported in the Company's Form 10-K for the year ended December 31, 2017.
[6]	As previously reported in the Company's Form 10-Q for the quarter ended September 30, 2017.
[7]	During the period from January 1, 2018 through August 31, 2018.
[8]	Net distributions to CEG primarily consist of distributions on Class B and D units in the amount of $27 million during the period from September 1, 2018 through September 30, 2018, partially offset by a non-cash contribution of $17 million made by CEG in connection with the formation of Repowering Partnership LLC.

Business Acquisitions Business Acquisitions - UPMC Thermal (Details)
$ in Millions

Mar. 31, 2018

USD ($)

Sep. 30, 2018

Jun. 19, 2018

USD ($)

^[1],[2]

5,405

UPMC Thermal [Member]

Business Combination, Consideration Transferred | $

$ 84

Accounts Payable, Related Parties | $

$ 5

Steam and Chilled Water Capacity, Megawatts Thermal Equivalent

^[1],[3]

1,392

UPMC Thermal [Member] | Thermal [Member]

^[1]

133

Steam and Chilled Water Capacity, Megawatts Thermal Equivalent

7.5

[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[2]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.
[3]	For thermal energy, net capacity represents MWt for steam or chilled water and excludes 134 MWt available under the right-to-use provisions contained in agreements between two of the Company's thermal facilities and certain of its customers.

Business Acquisitions Business Acquisitions - Central CA Fuel Cell (Details)
$ in Millions

Apr. 18, 2018

USD ($)

Sep. 30, 2018

Central CA Fuel Cell 1 [Member]

^[1],[2]

5,405

Business Combination, Consideration Transferred | $

$ 11

Power Purchase Agreement Period

2.8

20 years

[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[2]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.

Business Acquisitions Business Acquisitions - Buckthorn Solar Drop Down Asset (Details)
$ in Millions

Mar. 31, 2018

USD ($)

Sep. 30, 2018

USD ($)

Mar. 30, 2018

USD ($)

Dec. 31, 2017

USD ($)

^[1],[2]

5,405

$ 5,870

$ 6,083

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets

154

$ 20

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment

212

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets

235

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Financial Liabilities

^[3]

176

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities

191

Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value

$ 19

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

$ 25

$ 42

[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[2]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.
[3]	Net of $7 million of net debt issuance costs.

Business Acquisitions Business Acquisitions - November 2017 Drop Down (Details)
$ in Millions

3 Months Ended

9 Months Ended

Mar. 31, 2018

USD ($)

Nov. 02, 2017

USD ($)

Aug. 02, 2017

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Dec. 31, 2017

USD ($)

Nov. 01, 2017

USD ($)

$ 292

$ 269

^[1]

$ 824

$ 778

^[1]

100

^[1]

293

263

^[1]

Less: Pre-acquisition net (loss) income of Drop Down Assets

^[1]

145

^[1]

$ 0

(9)

^[1]

$ 4

^[1]

^[2],[3]

5,405

Less: Income attributable to noncontrolling interests

$ 5,870

$ 6,083

^[1]

Net Income (Loss) Available to Common Stockholders, Basic

$ 21

^[1]

$ 116

^[1]

$ 44

Less: Pre-acquisition net (loss) income of Drop Down Assets

(2)

(2)

154

Less: Income attributable to noncontrolling interests

$ 42

Net Income (Loss) Available to Common Stockholders, Basic

November 2017 Drop Down Assets [Member]

(8)

Less: Pre-acquisition net (loss) income of Drop Down Assets

(10)

(11)

(10)

Less: Income attributable to noncontrolling interests

$ 74

Net Income (Loss) Available to Common Stockholders, Basic

November 2017 Drop Down Assets [Member]

Previously Reported [Member]

$ 26

^[4]

265

767

^[4]

271

Less: Pre-acquisition net (loss) income of Drop Down Assets

^[4]

^[4]

Less: Income attributable to noncontrolling interests

^[4]

Net Income (Loss) Available to Common Stockholders, Basic

^[4]

$ 29

$ 54

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[3]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.
[4]	As previously reported in the Company's Form 10-Q for the quarter ended September 30, 2017.

Business Acquisitions Business Acquisitions - August 2017 Drop Down (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Mar. 31, 2018

Nov. 02, 2017

Aug. 02, 2017

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Aug. 01, 2017

$ 292

$ 269

^[1]

$ 824

$ 778

^[1]

100

^[1]

293

263

^[1]

Less: Pre-acquisition net (loss) income of Drop Down Assets

^[1]

145

^[1]

(9)

^[1]

Less: Income attributable to noncontrolling interests

^[1]

Net Income (Loss) Available to Common Stockholders, Basic

^[1]

116

^[1]

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

$ 42

Less: Pre-acquisition net (loss) income of Drop Down Assets

(2)

(2)

Less: Income attributable to noncontrolling interests

Net Income (Loss) Available to Common Stockholders, Basic

Business Combination, Contingent Consideration, Liability

$ 44

$ 8

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

$ 87

November 2017 Drop Down Assets [Member]

$ 74

(8)

Less: Pre-acquisition net (loss) income of Drop Down Assets

(10)

(11)

(10)

Less: Income attributable to noncontrolling interests

Net Income (Loss) Available to Common Stockholders, Basic

Business Acquisition, Percentage of Voting Interests Acquired

25.00%

Previously Reported [Member]

^[2]

265

767

^[2]

271

Less: Pre-acquisition net (loss) income of Drop Down Assets

^[2]

^[2]

Less: Income attributable to noncontrolling interests

^[2]

Net Income (Loss) Available to Common Stockholders, Basic

^[2]

$ 29

$ 54

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	As previously reported in the Company's Form 10-Q for the quarter ended September 30, 2017.

Business Acquisitions Business Acquisitions - March 2017 Drop Down (Details)
$ in Millions

Mar. 27, 2017

USD ($)

Sep. 30, 2018

USD ($)

Agua Caliente Borrower 2 [Member]

^[1],[2]

5,405

Percentage of NRG's Ownership

16.00%

31.00%

Power Purchase Agreement Period

25 years

Remaining Power Purchase Agreement term

22 years

Non-Recourse Debt

$ 41

Utah Portfolio [Member]

Remaining Power Purchase Agreement term

20 years

Percentage of Cash Available for Distributions

50.00%

Non-Recourse Debt

$ 287

March 2017 Drop Down Assets [Member]

Business Acquisition, Consideration Transferred, Working Capital

128

$ 3

Business Combination, Separately Recognized Transactions, Net Gains and Losses

$ 8

NRG [Member] | Agua Caliente Borrower 2 [Member]

NRG [Member] | Utah Portfolio [Member]

51.00%

Percentage of Cash Available for Distributions

50.00%

[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[2]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.

Variable Interest Entities Variable Interest Entities - Consolidated Entities (Details)
$ in Millions

3 Months Ended

9 Months Ended

May 31, 2018

USD ($)

Mar. 31, 2018

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Mar. 30, 2018

USD ($)

Dec. 31, 2017

USD ($)

Schedule of Equity Method Investments [Line Items]

^[1],[2]

5,405

$ 5,870

$ 6,083

2,591

2,597

^[3]

5,306

5,410

^[3]

8,500

8,489

^[3]

Less: Income attributable to noncontrolling interests

6,125

6,330

^[3]

$ 11

^[3]

$ 13

^[3]

November 2015 Drop Down Assets [Member]

Schedule of Equity Method Investments [Line Items]

192

354

548

Noncontrolling Interest in Variable Interest Entity

205

Alta X and XI TE Holdco [Member]

311

Schedule of Equity Method Investments [Line Items]

417

253

702

Noncontrolling Interest in Variable Interest Entity

Schedule of Equity Method Investments [Line Items]

621

Spring Canyon [Member]

Noncontrolling Interest in Variable Interest Entity

Schedule of Equity Method Investments [Line Items]

225

246

Noncontrolling Interest in Variable Interest Entity

136

Proceeds from Noncontrolling Interests

$ 66

$ 80

Less: Income attributable to noncontrolling interests

$ (55)

Schedule of Equity Method Investments [Line Items]

154

Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value

$ 42

$ 19

Less: Income attributable to noncontrolling interests

$ 0

Buckthorn Solar, due 2025 [Member]

Schedule of Equity Method Investments [Line Items]

Buckthorn Solar, due 2025 [Member] | Buckthorn Solar Drop Down Asset [Member]

$ 132

$ 169

Schedule of Equity Method Investments [Line Items]

CEG [Member] | Repowering Partnership LLC [Member]

$ 183

Schedule of Equity Method Investments [Line Items]

Payments for Deposits

Accounts Payable

$ 17

Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners

21.00%

[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[2]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.
[3]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Variable Interest Entities Variable Interest Entities - Unconsolidated Entities (Details)
$ in Millions

9 Months Ended

Sep. 30, 2018

USD ($)

Dec. 31, 2017

USD ($)

^[1]

Schedule of Equity Method Investments [Line Items]

$ 1,182

$ 1,178

Four Brothers Solar [Member]

^[2],[3]

5,405

Schedule of Equity Method Investments [Line Items]

Granite Mountain Holdings [Member]

$ 204

Schedule of Equity Method Investments [Line Items]

Iron Springs Holdings [Member]

Schedule of Equity Method Investments [Line Items]

Gen Conn Energy LLC [Member]

Schedule of Equity Method Investments [Line Items]

Schedule of Equity Method Investments [Line Items]

DGPV Holdco 1 [Member]

Payments to Acquire Interest in Subsidiaries and Affiliates

Due to Affiliate

$ 1

Schedule of Equity Method Investments [Line Items]

Remaining Lease Term

17 years

RPV Holdco [Member]

Schedule of Equity Method Investments [Line Items]

$ 42

DGPV Holdco 2 [Member]

Schedule of Equity Method Investments [Line Items]

DGPV Holdco 3 [Member]

Payments to Acquire Interest in Subsidiaries and Affiliates

Due to Affiliate

$ 10

Estimate of Fair Value Measurement [Member]

Remaining Lease Term

21 years

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2018.
[3]	The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,411 MWs.

Variable Interest Entities Variable Interest Entities - Utah Solar Portfolio (Details) - Utah Portfolio [Member]	Sep. 30, 2018
Variable Interest Entity [Line Items]
Percentage of Cash Available for Distributions	50.00%
Capital Unit, Class A [Member]
Variable Interest Entity [Line Items]
Percentage of Ownership	100.00%
Financial Institutions [Member] \| Capital Unit, Class B [Member]
Variable Interest Entity [Line Items]
Taxable Income Allocation, Pre-Flip	99.00%
Taxable Income Allocation, Post-Flip	50.00%

Fair Value of Financial Instruments Fair Value of Financial Instruments - Balance Sheet Grouping (Details) - USD ($)
$ in Millions

Sep. 30, 2018

Dec. 31, 2017

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Financing Receivable, Net

$ 3

$ 13

Long-term Debt and Capital Lease Obligations, Including Current Maturities

^[1]

5,835

6,099

Reported Value Measurement [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Financing Receivable, Net

Long-term Debt and Capital Lease Obligations, Including Current Maturities

^[1]

5,860

6,066

Fair Value, Inputs, Level 2 [Member] | Estimate of Fair Value Measurement [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Long-term Debt and Capital Lease Obligations, Including Current Maturities

1,451

1,502

Fair Value, Inputs, Level 3 [Member] | Estimate of Fair Value Measurement [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Long-term Debt and Capital Lease Obligations, Including Current Maturities

$ 4,384

$ 4,597

[1]	(a) Excludes deferred financing costs, which are recorded as a reduction to long-term debt on the Company's consolidated balance sheets.

Fair Value of Financial Instruments Fair Value of Financial Instruments - Recurring Fair Value (Details) - USD ($)

Sep. 30, 2018

Dec. 31, 2017

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

^[1]

$ 35,000,000

$ 2,000,000

Fair Value, Inputs, Level 2 [Member]

14,000,000

49,000,000

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]

^[2]

35,000,000

2,000,000

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Derivative Assets (Liabilities), at Fair Value, Net

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]

^[2]

14,000,000

49,000,000

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Derivative Assets (Liabilities), at Fair Value, Net

Commodity Contract [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

1,000,000

Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

1,000,000

^[3]

1,000,000

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

^[2]

1,000,000

Interest Rate Contract [Member]

^[2]

1,000,000

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

35,000,000

1,000,000

Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]

13,000,000

48,000,000

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

^[2]

35,000,000

1,000,000

^[2]

$ 13,000,000

$ 48,000,000

[1]	Derivative Assets balances classified as current are included within the prepayments and other current assets line item of the consolidated balance sheets as of September 30, 2018 and December 31, 2017.
[2]	(a) There were no derivative assets or liabilities classified as Level 1 or Level 3 as of September 30, 2018 and December 31, 2017.
[3]	There were no commodity contracts classified as derivative assets as of September 30, 2018.

Fair Value of Financial Instruments Fair Value of Financial Instruments - Credit Risk and Derivative FV Measurements (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018 USD ($)
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value Assets, Valuation Techniques, Impact of Credit Reserve to Fair Value	$ 0
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$ 2,500
Estimated Counterparty Credit Risk Exposure to Certain Counterparties, Period	5 years

Accounting for Derivative Instruments and Hedging Activities Accounting for Derivative Instruments and Hedging Activities - FV of Derivatives (Details) - USD ($)
$ in Millions

Sep. 30, 2018

Dec. 31, 2017

^[1]

$ 35

$ 2

Fair Value of Gross Derivative Assets/(Liabilities), Net

(47)

Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset

Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral

(47)

Derivative, Collateral, Right to Reclaim Cash

Derivative, Collateral, Obligation to Return Cash

Designated as Hedging Instrument [Member]

^[1]

Not Designated as Hedging Instrument [Member]

^[1]

Interest Rate Contract Current [Member] | Designated as Hedging Instrument [Member]

^[1]

Interest Rate Contract Current [Member] | Not Designated as Hedging Instrument [Member]

^[1]

Interest Rate Contract Non Current [Member] | Designated as Hedging Instrument [Member]

^[1]

Interest Rate Contract Non Current [Member] | Not Designated as Hedging Instrument [Member]

^[1]

Commodity Contract Current [Member] | Not Designated as Hedging Instrument [Member]

^[1]

Commodity Contract [Member]

Derivative Asset, Fair Value, Gross Liability

^[2]

Derivative Liability, Fair Value, Gross Asset

^[2]

Derivative Asset

Derivative Liability

^[2]

Fair Value of Gross Derivative Assets/(Liabilities), Net

(1)

^[2]

Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset

^[2]

Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral

(1)

^[2]

Interest Rate Contract [Member]

Derivative Asset, Fair Value, Gross Liability

Derivative Liability, Fair Value, Gross Asset

Derivative Asset

Derivative Liability

Fair Value of Gross Derivative Assets/(Liabilities), Net

(47)

Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset

Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral

(47)

Interest [Member] | United States of America, Dollars

Derivative, Notional Amount

1,909

2,050

Natural Gas [Member] | MMbtu [Member]

Derivative, Notional Amount

$ 2

[1]	Derivative Assets balances classified as current are included within the prepayments and other current assets line item of the consolidated balance sheets as of September 30, 2018 and December 31, 2017.
[2]	There were no commodity contracts classified as derivative assets as of September 30, 2018.

Accounting for Derivative Instruments and Hedging Activities Accounting for Derivative Instruments and Hedging Activities - AOCI (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Jun. 30, 2018

Dec. 31, 2017

Jun. 30, 2017

Dec. 31, 2016

Sep. 30, 2016

Derivative [Line Items]

Accumulated Other Comprehensive Loss, Net of Tax

$ (30)

$ (63)

$ (30)

$ (63)

$ (36)

$ (60)

$ (70)

Accumulated Other Comprehensive Loss, Cumulative Change in Loss from Cash Flow Hedges, Tax Amount

(5)

$ (16)

Reclassified from accumulated OCL to income due to realization of previously deferred amounts

Mark-to-market of cash flow hedge accounting contracts

(3)

Accumulated other comprehensive loss

(14)

(27)

(14)

(27)

$ (28)

^[1]

Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $1

(8)

Losses expected to be realized from OCL during the next 12 months, Tax Amount

(1)

Gain (Loss) on Cash Flow Hedge Ineffectiveness, Net

Noncontrolling Interest [Member]

Derivative [Line Items]

Accumulated other comprehensive loss

$ (16)

$ (36)

$ (16)

$ (36)

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Accounting for Derivative Instruments and Hedging Activities Accounting for Derivative Instruments and Hedging Activities - Impact to Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Interest Rate Contract [Member] \| Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized Gain (Loss) on Derivatives	$ (9)	$ (7)	$ (40)	$ (2)

Long-term Debt Long-term Debt - Debt Table (Details) - USD ($)
$ in Millions

9 Months Ended

12 Months Ended

Apr. 30, 2018

Sep. 30, 2018

Dec. 31, 2017

May 31, 2018

Current portion of long-term debt

$ 5,870

$ 6,083

(873)

^[1]

(339)

^[2]

Debt Issuance Costs, Net

(59)

(68)

Long-term Debt, Excluding Current Maturities

4,928

5,659

Debt Instrument, Unamortized Discount

^[3]

(10)

(17)

3.5% Convertible Notes due 2019 [Member]

$ 329

345

3.25% Convertible Notes due 2020 [Member]

^[4]

3.50%

$ 288

288

5.375% Senior Notes due in 2024 [Member]

^[4]

3.25%

Senior Notes

$ 500

500

5.00% Senior Notes due in 2026 [Member]

^[4]

5.375%

Senior Notes

$ 350

350

Revolving Credit Facility [Member]

^[4]

5.00%

Debt Instrument, Description of Variable Rate Basis

$ 0

$ 55

^[4],[5]

3 month LIBOR

Agua Caliente Borrower 2 [Member]

^[3]

1.75%

1.50%

^[5]

2.50%

$ 39

$ 41

Alpine Financing Agreement, due 2022 [Member]

^[4]

5.43%

Debt Instrument, Description of Variable Rate Basis

$ 129

135

^[4]

3-Month LIBOR

Alta Wind I-V, lease financing arrangement, due 2034 and 2035 [Member]

1.75%

Buckthorn Solar, due 2025 [Member]

$ 901

926

Debt Instrument, Description of Variable Rate Basis

$ 132

169

$ 132

1-Month LIBOR

1.75%

CVSR, due 2037

CVSR Holdco due 2037 [Member]

$ 720

746

$ 188

194

El Segundo Energy Center, due 2023

^[4]

4.68%

Debt Instrument, Description of Variable Rate Basis

$ 352

400

^[4]

3-Month LIBOR

West Holdings Credit Agreement due 2023 Tranche B [Member]

West Holdings Credit Agreement due 2023 Tranche A [Member]

2.375%

Energy Center Minneapolis Series C Notes, due 2025

1.75%

$ 0

Energy Center Minneapolis Series D Notes, due 2031

^[4]

5.95%

$ 125

125

Energy Center Minneapolis Series E, F, G, H Notes [Member]

^[4]

3.55%

$ 203

Laredo Ridge Wind, LLC, due in 2026 [Member]

Debt Instrument, Description of Variable Rate Basis

$ 91

^[4]

3-Month LIBOR

Marsh Landing Term Loan Facility [Member]

1.875%

Debt Instrument, Description of Variable Rate Basis

$ 280

318

^[4]

3-Month LIBOR

Tapestry Wind LLC due in 2021 [Member]

2.125%

Debt Instrument, Description of Variable Rate Basis

$ 154

162

^[4]

3-Month LIBOR

Utah Solar Portfolio, due 2022 [Member]

1.625%

Viento Funding II, Inc., due in 2023 [Member]

$ 273

278

Debt Instrument, Description of Variable Rate Basis

$ 154

163

^[4]

3-Month LIBOR

Walnut Creek Energy, LLC, due in 2023 [Member]

3.00%

Debt Instrument, Description of Variable Rate Basis

$ 235

267

^[4]

3-Month LIBOR

1.625%

Other Debt [Member]

$ 427

443

Project [Domain]

Minimum [Member] | Alta Wind I-V, lease financing arrangement, due 2034 and 2035 [Member]

$ 4,403

$ 4,545

Minimum [Member] | CVSR, due 2037

5.696%

Maximum [Member] | Alta Wind I-V, lease financing arrangement, due 2034 and 2035 [Member]

2.339%

Maximum [Member] | CVSR, due 2037

7.015%

Letter of Credit [Member] | Revolving Credit Facility [Member]

3.775%

Letter of Credit [Member] | Agua Caliente Borrower 2 [Member]

$ 70

Letter of Credit [Member] | Alpine Financing Agreement, due 2022 [Member]

Letter of Credit [Member] | Alta Wind I-V, lease financing arrangement, due 2034 and 2035 [Member]

Letter of Credit [Member] | Buckthorn Solar, due 2025 [Member]

103

Letter of Credit [Member] | CVSR, due 2037

Letter of Credit [Member] | CVSR Holdco due 2037 [Member]

Letter of Credit [Member] | El Segundo Energy Center, due 2023

Letter of Credit [Member] | Energy Center Minneapolis Series C Notes, due 2025

138

Letter of Credit [Member] | Energy Center Minneapolis Series D Notes, due 2031

Letter of Credit [Member] | Laredo Ridge Wind, LLC, due in 2026 [Member]

Letter of Credit [Member] | Marsh Landing Term Loan Facility [Member]

Letter of Credit [Member] | Tapestry Wind LLC due in 2021 [Member]

Letter of Credit [Member] | Utah Solar Portfolio, due 2022 [Member]

Letter of Credit [Member] | Viento Funding II, Inc., due in 2023 [Member]

Letter of Credit [Member] | Walnut Creek Energy, LLC, due in 2023 [Member]

$ 82

[1]	Current maturities reflect the results of the 2019 Convertible Notes and 2020 Convertible Notes tender offer, as further described below.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	Discounts relate to the 2019 Convertible Notes and 2020 Convertible Notes.
[4]	As of September 30, 2018, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023 where L+ equals 6 month LIBOR plus 3.00%
[5]	Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement.

Long-term Debt Long-term Debt - Debt Disclosures (Details) - USD ($)
$ in Millions

1 Months Ended

9 Months Ended

12 Months Ended

Oct. 10, 2018

Oct. 02, 2018

Aug. 31, 2018

Jun. 19, 2018

Apr. 30, 2018

Aug. 31, 2018

Sep. 30, 2018

Dec. 31, 2017

Oct. 09, 2018

Oct. 01, 2018

Revolving Credit Facility [Member]

$ 5,870.0

$ 6,083.0

Line of Credit Facility, Fair Value of Amount Outstanding

$ 0.0

^[1]

1.75%

1.50%

^[2]

2.50%

3.5% Convertible Notes due 2019 [Member]

$ 0.0

$ 55.0

$ (16.0)

$ 329.0

345.0

3.25% Convertible Notes due 2020 [Member]

^[3]

3.50%

$ 288.0

288.0

Intercompany Credit Agreement due 2019 [Member]

^[3]

3.25%

CVSR Holdco due 2037 [Member]

(16.0)

$ 188.0

194.0

^[3]

4.68%

NRG Energy Center Minneapolis Series E Notes [Member]

1.75%

$ 70.0

NRG Energy Center Minneapolis Series F Notes [Member]

^[3]

4.80%

10.0

NRG Energy Center Minneapolis Series G Notes [Member]

^[3]

4.60%

83.0

NRG Energy Center Minneapolis Series H Notes [Member]

^[3]

5.90%

40.0

Energy Center Minneapolis Series E, F, G, H Notes [Member]

^[3]

4.83%

203.0

$ 0.0

Proceeds from (Repayments of) Debt

203.0

0.0

120.0

Energy Center Minneapolis Series C Notes, due 2025

$ (83.0)

$ 0.0

$ 83.0

^[3]

5.95%

Line of Credit Facility, Maximum Borrowing Capacity

$ 40.0

Letter of Credit [Member] | Revolving Credit Facility [Member]

Letter of Credit [Member] | CVSR Holdco due 2037 [Member]

70.0

Letter of Credit [Member] | Energy Center Minneapolis Series C Notes, due 2025

13.0

$ 0.0

Bridge Loan [Member]

Line of Credit Facility, Maximum Borrowing Capacity

$ 1,500.0

Debt Instrument, Basis Spread on Libor Rate

3.00%

Buckthorn Solar Drop Down Asset [Member] | Buckthorn Solar Drop Down Asset [Member]

2.00%

Derivative, Nonmonetary Notional Amount, Percent of Required Need, Coverage

80.00%

Subsequent Event [Member] | 5.75% Senior Notes due 2025 [Member]

$ 600.0

Subsequent Event [Member] | 3.5% Convertible Notes due 2019 [Member]

5.75%

$ (109.0)

Subsequent Event [Member] | 3.25% Convertible Notes due 2020 [Member]

$ 220.0

$ (243.0)

Subsequent Event [Member] | Letter of Credit [Member] | Revolving Credit Facility [Member]

45.0

Subsequent Event [Member] | Bridge Loan [Member]

$ 45.0

Line of Credit Facility, Maximum Borrowing Capacity

$ 867.5

[1]	Discounts relate to the 2019 Convertible Notes and 2020 Convertible Notes.
[2]	Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement.
[3]	As of September 30, 2018, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023 where L+ equals 6 month LIBOR plus 3.00%

Earnings Per Share (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

Net Income (Loss) Available to Common Stockholders, Basic

$ 21

$ 29

^[1]

$ 116

$ 54

^[1]

Common Class A [Member]

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

Net Income (Loss) Available to Common Stockholders, Basic

^[2]

$ 7

$ 10

$ 40

$ 19

Weighted Average Number of Shares Outstanding, Basic

^[2]

Net Income (Loss) Available to Common Stockholders, Diluted

^[2]

$ 0.20

$ 0.30

$ 1.14

$ 0.56

^[2]

$ 7

$ 13

$ 40

$ 19

Weighted Average Number of Shares Outstanding, Diluted

^[2]

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

^[2]

$ 0.20

$ 0.27

$ 1.14

$ 0.56

Common Class C [Member]

Net Income (Loss) Available to Common Stockholders, Basic

^[2]

$ 14

$ 19

$ 76

$ 35

Weighted Average Number of Shares Outstanding, Basic

^[2]

Net Income (Loss) Available to Common Stockholders, Diluted

^[2]

$ 0.20

$ 0.30

$ 1.14

$ 0.56

^[2]

$ 14

$ 21

$ 85

$ 35

Weighted Average Number of Shares Outstanding, Diluted

^[2]

3.5% Convertible Notes due 2019 [Member] | Common Class A [Member]

^[2]

$ 0.20

$ 0.29

$ 1.10

$ 0.56

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount

3.25% Convertible Notes due 2020 [Member] | Common Class C [Member]

Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]

Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Basic and diluted earnings per share might not recalculate due to presenting values in millions rather than whole dollars.

Changes in Capital Structure Changes in Capital Structure - Stock Issuance (Details) - USD ($) $ / shares in Units, $ in Thousands		9 Months Ended
	Sep. 27, 2018	Sep. 30, 2018
Class of Stock [Line Items]
Common Stock, Par or Stated Value Per Share		$ 0.01
ATM Program, Maximum Dollar Value of Shares to Be Issued		$ 150,000
Sale of Stock, Number of Shares Issued in Transaction	3,916,449	4,392,583
Proceeds from Issuance or Sale of Equity	$ 75,000
Proceeds from Issuance of Common Stock, Before Commission Fees		$ 77,000
Commission Fees		762
ATM program, dollar value of shares remaining		$ 38,000
Clearway Energy LLC [Member] \| CEG [Member]
Class of Stock [Line Items]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest		44.30%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Voting Interest		55.00%

Changes in Capital Structure Changes in Capital Structure - Dividends (Details) - $ / shares	3 Months Ended				9 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Class of Stock [Line Items]
Dividends Per Common Share, Cash Paid	$ 0.320	$ 0.309	$ 0.298
Dividends Payable, Date Declared					Oct. 31, 2018
Common Stock, Dividends, Per Share, Declared					$ 0.331
Dividends Payable, Date to be Paid					Dec. 17, 2018
Dividends Payable, Date of Record					Dec. 03, 2018
Preferred Stock, Shares Authorized	10,000,000				10,000,000		10,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01				$ 0.01
Common Class A [Member]
Class of Stock [Line Items]
Dividends Per Common Share, Cash Paid	0.320			$ 0.28	0.927	$ 0.81
Common Class C [Member]
Class of Stock [Line Items]
Dividends Per Common Share, Cash Paid	$ 0.320			$ 0.28	$ 0.927	$ 0.81

Segment Reporting (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Dec. 31, 2017

^[1]

$ 292

$ 269

^[1]

$ 824

$ 778

^[1]

247

241

^[1]

247

246

^[1]

^[1]

100

^[1]

293

263

^[1]

^[1]

^[1]

^[1]

(2)

^[1]

(74)

^[1]

(200)

(239)

^[1]

^[1]

162

^[1]

^[1]

^[1]

145

^[1]

8,500

$ 8,489

Conventional Generation

251

246

131

116

(13)

(33)

(39)

107

107

1,811

152

135

427

402

106

102

154

167

134

(2)

(36)

(38)

(95)

(130)

131

131

5,952

146

130

(4)

(2)

(8)

(7)

512

(24)

(4)

(37)

(16)

(21)

(64)

(63)

(44)

(25)

(100)

(78)

(55)

$ (33)

(117)

$ (93)

Income Tax Expense (Benefit), Continuing Operations [Abstract]

$ 225

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Income Taxes (Provision) (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2018

Sep. 30, 2017

Sep. 30, 2018

Sep. 30, 2017

Income before income taxes

$ 60

$ 39

^[1]

$ 162

$ 88

^[1]

Effective income tax rate

$ 11

$ 8

^[1]

$ 17

$ 15

^[1]

18.30%

20.50%

10.50%

17.00%

U.S. federal statutory rate (as a percent)

21.00%

35.00%

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Related Party Transactions (Details)
$ in Millions

2 Months Ended

3 Months Ended

8 Months Ended

9 Months Ended

Mar. 31, 2018

USD ($)

Aug. 31, 2018

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Aug. 31, 2018

USD ($)

Sep. 30, 2018

USD ($)

Sep. 30, 2017

USD ($)

Jun. 19, 2018

USD ($)

Dec. 31, 2017

USD ($)

$ 6

$ 4

^[1]

$ 17

$ 14

^[1]

^[2],[3]

5,405

NRG [Member]

Revenue from Related Parties

$ 2

$ 8

RENOM [Member]

Thermal [Member] | NRG [Member]

$ 7

$ 22

Due to Affiliate

$ 5

Marsh Landing [Member] | NRG [Member]

NRG Yield [Member] | NRG [Member]

Operations and Maintenance services [Member] | NRG [Member]

Operations and Maintenance services [Member] | GCE Holding LLC [Member] | NRG [Member]

Management Service, Base [Member] | NRG [Member]

$ 1

$ 4

$ 9

Steam and Chilled Water Capacity, Megawatts Thermal Equivalent | MW

^[2],[4]

1,392

Thermal [Member] | Energy Center Dover [Member]

^[2]

133

Thermal [Member] | Thermal [Member]

^[2]

103

Thermal [Member] | UPMC Thermal [Member]

^[2]

Steam and Chilled Water Capacity, Megawatts Thermal Equivalent | MW

7.5

UPMC Thermal [Member]