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Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2017	Apr. 30, 2017
Class of Stock [Line Items]
Entity Registrant Name	NRG Yield LLC
Entity Central Index Key	0001637757
Document Type	10-Q
Document Period End Date	Mar. 31, 2017
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	Yes
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1
Common Class A [Member]
Class of Stock [Line Items]
Entity Common Stock, Shares Outstanding		34,586,250
Common Class B [Member]
Class of Stock [Line Items]
Entity Common Stock, Shares Outstanding		42,738,750
Common Class C [Member]
Class of Stock [Line Items]
Entity Common Stock, Shares Outstanding		63,213,831
Common Class D [Member]
Class of Stock [Line Items]
Entity Common Stock, Shares Outstanding		42,738,750

Condensed Consolidated Statements of Operations - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Operating Revenues

Total operating revenues

$ 218

$ 234

^[1],[2]

Operating Costs and Expenses [Abstract]

Cost of operations

^[1]

Depreciation and amortization

^[1],[2]

General and administrative

^[1],[2]

^[1]

Total operating costs and expenses

164

161

^[1]

Operating Income

^[2]

Costs and Expenses [Abstract]

Equity in earnings of unconsolidated affiliates

^[1],[2],[3]

Other income, net

^[1]

Interest expense

(73)

(71)

^[1],[2]

Total other expense, net

(53)

(67)

^[1]

Net Income

^[1],[2],[3]

Less: Net loss attributable to noncontrolling interests

(9)

(11)

^[1]

Net Income Attributable to NRG Yield LLC

^[1]

Consolidation, Eliminations [Member]

Operating Revenues

Total operating revenues

^[4]

^[5]

Operating Costs and Expenses [Abstract]

Cost of operations

^[4]

^[5]

Depreciation and amortization

^[4]

^[5]

General and administrative

^[4]

^[5]

^[4]

Total operating costs and expenses

^[4]

^[5]

Operating Income

^[4]

^[5]

Costs and Expenses [Abstract]

Equity in earnings of unconsolidated affiliates

^[4]

^[5]

Other income, net

^[4]

Interest expense

^[4]

^[5]

Total other expense, net

(22)

^[4]

(31)

^[5]

Net Income

(22)

(31)

^[5]

Less: Net loss attributable to noncontrolling interests

^[4]

^[5]

Net Income Attributable to NRG Yield LLC

$ (23)

^[4]

$ (31)

^[5]

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	Three months ended March 31, 2016(In millions)Conventional Generation Renewables Thermal Corporate TotalOperating revenues$79 $111 $44 $— $234Cost of operations23 33 29 — 85Depreciation and amortization20 49 5 — 74General and administrative— — — 2 2Operating income (loss)36 29 10 (2) 73Equity in earnings of unconsolidated affiliates3 1 — — 4Interest expense(11) (42) (2) (16) (71)Net Income (Loss)$28 $(12) $8 $(18) $6
[3]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[4]	All significant intercompany transactions have been eliminated in consolidation.
[5]	(a) All significant intercompany transactions have been eliminated in consolidation.

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Net Income

$ 1

$ 6

^[1],[2],[3]

Other Comprehensive Loss, net of tax

Unrealized gain (loss) on derivatives

(50)

^[4]

Other comprehensive income (loss)

(50)

^[4]

Comprehensive Income (Loss)

(44)

^[4]

Less: Comprehensive loss attributable to noncontrolling interests

(9)

(12)

^[4]

Comprehensive Income (Loss) Attributable to NRG Yield LLC

$ 17

$ (32)

^[4]

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	Three months ended March 31, 2016(In millions)Conventional Generation Renewables Thermal Corporate TotalOperating revenues$79 $111 $44 $— $234Cost of operations23 33 29 — 85Depreciation and amortization20 49 5 — 74General and administrative— — — 2 2Operating income (loss)36 29 10 (2) 73Equity in earnings of unconsolidated affiliates3 1 — — 4Interest expense(11) (42) (2) (16) (71)Net Income (Loss)$28 $(12) $8 $(18) $6
[4]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Consolidated Balance Sheets - USD ($)

Mar. 31, 2017

Dec. 31, 2016

Current Assets

Cash and cash equivalents

$ 210,000,000

$ 321,000,000

^[1]

Restricted cash

106,000,000

165,000,000

^[1]

Accounts receivable — trade

82,000,000

92,000,000

^[1]

Accounts receivable — affiliate

3,000,000

1,000,000

^[1]

Inventory

40,000,000

39,000,000

^[1]

Notes receivable

15,000,000

16,000,000

^[1]

Derivative instruments — affiliate

1,000,000

2,000,000

^[1]

Prepayments and other current assets

19,000,000

20,000,000

^[1]

Total current assets

476,000,000

656,000,000

^[1]

Property, plant and equipment

Less accumulated depreciation

(1,025,000,000)

(951,000,000)

Property, plant and equipment, net

5,390,000,000

5,460,000,000

^[1]

Other Assets

Equity investments in affiliates

1,154,000,000

1,152,000,000

^[1]

Notes receivable

10,000,000

14,000,000

^[1]

Intangible assets, net

1,268,000,000

1,286,000,000

^[1]

Derivative instruments

2,000,000

1,000,000

Other non-current assets

66,000,000

51,000,000

^[1]

Total other assets

2,500,000,000

2,504,000,000

^[1]

Total Assets

8,366,000,000

8,620,000,000

^[1]

Current Liabilities

Current portion of long-term debt — external

296,000,000

291,000,000

^[1]

Accounts payable — trade

26,000,000

23,000,000

^[1]

Accounts payable — affiliate

50,000,000

40,000,000

^[1]

Derivative instruments

28,000,000

32,000,000

^[1]

Accrued expenses and other current liabilities

54,000,000

85,000,000

^[1]

Total current liabilities

454,000,000

471,000,000

^[1]

Other Liabilities

Long-term debt — external

5,061,000,000

5,098,000,000

^[1]

Long-term debt — affiliate

618,000,000

^[1]

Due to Related Parties, Noncurrent

6,000,000

9,000,000

^[1]

Derivative instruments

40,000,000

44,000,000

^[1]

Other non-current liabilities

79,000,000

76,000,000

^[1]

Total non-current liabilities

5,804,000,000

5,845,000,000

^[1]

Total Liabilities

6,258,000,000

6,316,000,000

^[1]

Commitments and Contingencies

Members' Equity

Contributed capital

1,865,000,000

1,995,000,000

^[1]

Retained earnings

6,000,000

79,000,000

^[1]

Accumulated other comprehensive loss

(76,000,000)

(83,000,000)

^[1]

Noncontrolling interest

313,000,000

^[1]

Total Members' Equity

2,108,000,000

2,304,000,000

^[1]

Total Liabilities and Members’ Equity

$ 8,366,000,000

$ 8,620,000,000

^[1]

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

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Cash Flows from Operating Activities

Net Income

$ 1

$ 6

^[1],[2],[3]

Adjustments to reconcile net (loss) income to net cash provided by operating activities:

Income (Loss) from Equity Method Investments

^[1],[2],[3]

Distributions from unconsolidated affiliates

^[2]

Depreciation, Amortization and Accretion, Net

^[2]

Amortization of financing costs

^[2]

Amortization of Intangibles and Out of Market Contracts

^[2]

Changes in derivative instruments

(3)

^[2]

Disposal of asset components and ARO accretion

(3)

^[2]

Changes in prepaid and accrued capacity payments

^[2]

Changes in other working capital

^[2]

Net Cash Provided by Operating Activities

^[2]

Cash Flows from Investing Activities

Payment to Acquire Business under Common Control

131

^[2]

Capital expenditures

(4)

(7)

^[2]

Decrease in restricted cash

(59)

(23)

^[2]

Cash receipts from notes receivable

^[2]

Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital

^[2]

Investments in unconsolidated affiliates

(7)

(51)

^[2]

Other

(2)

^[2]

Net Cash Provided by (Used in) Investing Activities

(63)

(21)

^[2]

Cash Flows from Financing Activities

Net contributions from noncontrolling interests

^[2]

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

(38)

(11)

^[2]

Proceeds from the issuance of Class C units

Payments of distributions

(53)

(45)

^[2]

Payments of Debt Issuance Costs

(3)

^[2]

Proceeds from Lines of Credit

^[2]

Payments for the revolving credit facility

Proceeds from the issuance of long-term debt — external

^[2]

Repayments of Long-term Debt

(75)

(67)

Net Cash Used in Financing Activities

(109)

(103)

^[2]

Net Decrease in Cash and Cash Equivalents

(111)

(35)

^[2]

Cash and Cash Equivalents at Beginning of Period

321

^[4]

$ 110

^[2]

Cash and Cash Equivalents at End of Period

$ 210

[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	Three months ended March 31, 2016(In millions)Conventional Generation Renewables Thermal Corporate TotalOperating revenues$79 $111 $44 $— $234Cost of operations23 33 29 — 85Depreciation and amortization20 49 5 — 74General and administrative— — — 2 2Operating income (loss)36 29 10 (2) 73Equity in earnings of unconsolidated affiliates3 1 — — 4Interest expense(11) (42) (2) (16) (71)Net Income (Loss)$28 $(12) $8 $(18) $6
[4]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Nature of Business

3 Months Ended

Mar. 31, 2017

Nature of Business Disclosure [Abstract]

Business Description and Basis of Presentation [Text Block]

Nature of Business

NRG Yield LLC, together with its consolidated subsidiaries, or the Company, was formed by NRG as a Delaware limited liability company on March 5, 2013, to serve as the primary vehicle through which NRG owns, operates and acquires contracted renewable and conventional generation and thermal infrastructure assets. NRG owns 100% of NRG Yield LLC's Class B units and Class D units and receives distributions through its ownership of these units. Yield, Inc. owns 100% of NRG Yield LLC's Class A units and Class C units.

The Company owns a diversified portfolio of contracted renewable and conventional generation and thermal infrastructure assets in the U.S. The Company’s contracted generation portfolio collectively represents 4,879 net MW as of March 31, 2017. Each of these assets sells substantially all of its output pursuant to long-term offtake agreements with creditworthy counterparties. The weighted average remaining contract duration of these offtake agreements was approximately 16 years as of March 31, 2017 based on CAFD. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,319 net MWt and electric generation capacity of 123 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 following table represents the structure of the Company as of March 31, 2017:

As of March 31, 2017, 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
CVSR	100	%	250	Pacific Gas and Electric	2038
Desert Sunlight 250	25	%	63	Southern California Edison	2035
Desert Sunlight 300	25	%	75	Pacific Gas and Electric	2040
Kansas South	100	%	20	Pacific Gas and Electric	2033
Roadrunner	100	%	20	El Paso Electric	2031
TA High Desert	100	%	20	Southern California Edison	2033
Utah Solar Portfolio^(e)	50	%	265	PacifiCorp	2036
			921
Distributed Solar
Apple I LLC Projects	100	%	9	Various	2032
AZ DG Solar Projects	100	%	5	Various	2025 - 2033
			14
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)}	74.3	%	16	Corn Belt Power Cooperative	2027
Elbow Creek ^{(b) (f)}	75	%	92	NRG Power Marketing LLC	2022
Elkhorn Ridge ^{(b) (f)}	50.3	%	41	Nebraska Public Power District	2029
Forward ^{(b) (f)}	75	%	22	Constellation NewEnergy, Inc.	2017
Goat Wind ^{(b) (f)}	74.9	%	113	Dow Pipeline Company	2025
Hardin ^{(b) (f)}	74.3	%	11	Interstate Power and Light Company	2027
Laredo Ridge	100	%	80	Nebraska Public Power District	2031
Lookout ^{(b) (f)}	75	%	29	Southern Maryland Electric Cooperative	2030
Odin ^{(b) (f)}	74.9	%	15	Missouri River Energy Services	2028
Pinnacle	100	%	55	Maryland Department of General Services and University System of Maryland	2031
San Juan Mesa ^{(b) (f)}	56.3	%	68	Southwestern Public Service Company	2025
Sleeping Bear ^{(b) (f)}	75	%	71	Public Service Company of Oklahoma	2032
South Trent	100	%	101	AEP Energy Partners	2029
Spanish Fork ^{(b) (f)}	75	%	14	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)}	74.9	%	121	Southwestern Public Service Company	2027



Projects	Percentage Ownership		Net Capacity (MW)^(a)	Offtake Counterparty	Expiration
			1,999
Thermal
Thermal equivalent MWt ^(c)	100	%	1,319	Various	Various
NRG Dover Energy Center LLC	100	%	103	NRG Power Marketing LLC	2018
Thermal generation	100	%	20	Various	Various
			1,442
Total net capacity (excluding equivalent MWt)^(d)			5,002

^(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 March 31, 2017.

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

^(c) 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.

^(d) 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 5,008 MWs.

^(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 NRG Wind TE Holdco portfolio.

In addition to the facilities owned or leased in the table above, the Company 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 151 MW based on cash to be distributed. For further discussions, refer to Note 3, Investments Accounted for by the Equity Method and Variable Interest Entities to the Consolidated Financial Statements.

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.

As further described in Note 3, Investments Accounted for by the Equity Method and Variable Interest Entities, on March 27, 2017, the Company acquired the following interests from NRG, referred to as the March 2017 Drop Down Assets: (i) Agua Caliente Borrower 2 LLC, which owns a 16% interest in the Agua Caliente solar farm, one of the NRG ROFO assets and (ii) NRG's interests in seven utility-scale solar farms located in Utah that were part of NRG's November 2, 2016 acquisition of projects from SunEdison, or the Utah Solar Portfolio. The Company paid total cash consideration of $130 million, plus a $1 million working capital adjustment, and assumed non-recourse debt of $328 million, which is consolidated, as well as its pro-rata share of non-recourse project-level debt of $135 million. The acquisition was funded with cash on hand. The acquisition of the March 2017 Drop Down Assets was accounted for as 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). Accordingly, in connection with the retrospective adjustment of prior periods, the Company adjusted its financial statements to reflect its results of operations, financial position and cash flows as if it recorded its interests in the Aqua Caliente Borrower 2 LLC on January 1, 2016, and its interests in the Utah Solar Portfolio on November 2, 2016.

In addition, the Company's results of operations for the three months ended March 31, 2016 were recast for the Company's acquisition of the CVSR Drop Down Asset on September 1, 2016; refer to Note 3, Business Acquisitions, in the Company's 2016 Report on Form 10-K for additional information.

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 Company's audited consolidated financial statements for the year ended December 31, 2016 included in the 2016 Form 10-K. Interim results are not necessarily indicative of results for a full year.

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 March 31, 2017, and the results of operations, comprehensive income (loss) and cash flows for the three months ended March 31, 2017 and 2016.

Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2017

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 March 31, 2017 and December 31, 2016:



	March 31, 2017		December 31, 2016
	(In millions)
Property, Plant and Equipment Accumulated Depreciation	$	1,025	$	951
Intangible Assets Accumulated Amortization	181		163

Noncontrolling Interests

The following table reflects the changes in the Company's noncontrolling interest balance:



	(In millions)
Balance as of December 31, 2016	313
Capital contributions from tax equity investors, net of distributions	14
Comprehensive income	(9		)
Distributions to NRG for its 25% interest in TE Holdco	(5		)
Balance as of March 31, 2017	$	313

Distributions

The following table lists the distributions paid on NRG Yield LLC's Class A, B, C and D units during the three months ended March 31, 2017:



	First Quarter 2017
Distributions per Class A, B, C and D unit	$	0.26

On April 25, 2017, the Company declared a distribution on its Class A, Class B, Class C and Class D units of $0.27 per unit payable on June 15, 2017 to unit holders of record as of June 1, 2017.

Reclassifications

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

Recent Accounting Developments

ASU 2016-18 — In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230), Restricted Cash, or ASU No. 2016-18. The amendments of ASU No. 2016-18 require an entity to include amounts generally described as restricted cash and restricted cash equivalents with cash and cash equivalents when reconciling the beginning of period and end of period total amounts on the statement of cash flows. The amendments of ASU No. 2016-18 are effective for annual reporting periods beginning after December 15, 2017, and interim periods within those annual periods. Early adoption is permitted and the adoption of ASU No. 2016-18 will be applied retrospectively. The Company calculated the impact of the ASU No. 2016-18 on its statement of cash flows to be a decrease of $59 million and $23 million in the net cash used in investing activities for the three months ended March 31, 2017 and 2016, respectively.

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 expects to adopt the standard effective January 1, 2019 utilizing the required modified retrospective approach for the earliest period presented. The Company 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. As this review is still in process, it is currently not practicable to quantify the impact of adopting Topic 842 at this time.

ASU 2014-09 — In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), or ASU No. 2014-09, which was further amended through various updates issued by the FASB thereafter. The amendments of ASU No. 2014-09 completed the joint effort between the FASB and the IASB, to develop a common revenue standard for GAAP and IFRS, and to improve financial reporting. The guidance under Topic 606 provides that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for the goods or services provided and establishes a five step model to be applied by an entity in evaluating its contracts with customers. The Company expects to adopt the standard effective January 1, 2018 and apply the guidance retrospectively to contracts at the date of adoption. The Company will recognize the cumulative effect of applying Topic 606 at the date of initial application, as prescribed under the modified retrospective transition method. The Company also expects to elect the practical expedient available under Topic 606 for measuring progress toward complete satisfaction of a performance obligation and for disclosure requirements of remaining performance obligations. The practical expedient allows an entity to recognize revenue in the amount to which the entity has the right to invoice such that the entity has a right to the consideration in an amount that corresponds directly with the value to the customer for performance completed to date by the entity. The majority of the Company's revenues are obtained through PPAs, which are currently accounted for as operating leases. In connection with the implementation of Topic 842, as described above, the Company expects to elect certain of the practical expedients permitted, including the expedient that permits the Company to retain its existing lease assessment and classification. As leases are excluded from the scope of Topic 606, the Company expects the standard to have an immaterial impact on the Company's results of operations, cash flows and financial position; however, the Company continues to assess the impact in connection with its plan of adoption.

Variable Interest Entities

3 Months Ended

Mar. 31, 2017

Equity Method Investments and Joint Ventures [Abstract]

Investments Accounted for by the Equity Method and Variable Interest Entities

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 NRG 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 $130 million, plus $1 million of working capital. 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 $328 million, which it consolidates, as further described in Note 6, Long-term Debt, as well as its pro-rata share of non-recourse project-level debt of $135 million, as further described below.

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 $139 million was recorded as an adjustment to the Company's contributed capital. 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).

The following is a summary of assets and liabilities transferred in connection with the acquisition of the March 2017 Drop Down Assets as of March 27, 2017:



	(In millions)
Assets:
Cash	$	6
Equity investment in projects	456
Total assets acquired	462
Liabilities:
Debt (Current and non-current) ^(a)	320
Other current and non-current liabilities	3
Total liabilities assumed	323
Net assets acquired	$	139

^(a) Net of $8 million of debt issuance costs.

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 Company's 2016 Form 10-K.

Summarized financial information for the Company's consolidated VIEs consisted of the following as of March 31, 2017:



(In millions)	NRG Wind TE Holdco		Alta Wind TE Holdco		Spring Canyon
Other current and non-current assets	$	193	$	18	$	4
Property, plant and equipment	435		455		99
Intangible assets	2		271		—
Total assets	630		744		103
Current and non-current liabilities	210		8		6
Total liabilities	210		8		6
Noncontrolling interest	141		106		66
Net assets less noncontrolling interests	$	279	$	630	$	31

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 Company's 2016 Form 10-K.

The Company's maximum exposure to loss as of March 31, 2017 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	$	228
Granite Mountain Holdings, LLC	81
Iron Springs Holdings, LLC	54
NRG DGPV Holdco 1 LLC	73
NRG DGPV Holdco 2 LLC	34
NRG RPV Holdco 1 LLC	70
GenConn Energy LLC	104

Utah Solar Portfolio — As described above, 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, or TE Investor, who receives 99% of allocations of taxable income and other items until 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 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.

The following tables present summarized financial information for the Company's significant equity method investments:



	Three months ended March 31,
(In millions)	2017			2016
Income Statement Data:
Utah Solar Portfolio
Operating revenues	$	13		$	—
Operating loss	(2		)	—
Net loss	(2		)	—
GenConn Energy LLC
Operating revenues	$	17		$	18
Operating income	9			9
Net income	6			7
	March 31, 2017			December 31, 2016
Balance Sheet Data:	(In millions)
Utah Solar Portfolio
Current assets	$	15		$	20
Non-current assets	1,109			1,105
Current liabilities	3			14
Non-current liabilities	21			38
GenConn Energy LLC
Current assets	$	29		$	36
Non-current assets	385			389
Current liabilities	12			16
Non-current liabilities	193			196

Non-recourse project-level debt of unconsolidated affiliates

Agua Caliente Financing — As described above, the Company acquired a 16% interest in the Agua Caliente solar facility through its acquisition of Agua Caliente Borrower 2 LLC. As of March 31, 2017, Agua Caliente Solar LLC, the direct owner of the Agua Caliente solar facility, had $846 million outstanding under the Agua Caliente financing agreement with the Federal Financing Bank, or FFB, borrowed to finance the costs of constructing the facility. The Company's pro-rata share of Agua Caliente Financing was approximately $135 million as of March 31, 2017. Amounts borrowed under the Agua Caliente financing agreement accrue interest at a fixed rate based on U.S. Treasury rates plus a spread of 0.375%, mature in 2037 and are secured by the assets of Agua Caliente Solar LLC. The loans provided by the FFB are guaranteed by the U.S. DOE.

Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2017

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 receivable — affiliate, accounts payable, current portion of the 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 March 31, 2017				As of December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Assets:
Notes receivable, including current portion	$	25	$	25	$	30	$	30
Liabilities:
Long-term debt — affiliate	618		613		618		608
Long-term debt — external, including current portion	$	5,418	$	5,413	$	5,451	$	5,435

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 debt securities, 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 March 31, 2017 and December 31, 2016:



	As of March 31, 2017				As of December 31, 2016
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	844	$	5,182	$	833	$	5,210

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 March 31, 2017		As of December 31, 2016
	Fair Value ^(a)		Fair Value ^(a)		Fair Value ^(a)
(In millions)	Level 2		Level 1		Level 2
Derivative assets:
Commodity contracts	$	1	$	1	$	1
Interest rate contracts	2		—		1
Total assets	3		1		2
Derivative liabilities:
Commodity contracts	2		—		1
Interest rate contracts	66		—		75
Total liabilities	$	68	$	—	$	76

^(a) There were no derivative assets or liabilities classified as Level 1 as of March 31, 2017. There were no derivative assets or liabilities classified as Level 3 as of March 31, 2017 and December 31, 2016.

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 NRG's 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 March 31, 2017, the credit reserve resulted in a $1 million increase in fair value 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 Company's 2016 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) daily 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 March 31, 2017, credit risk exposure to these counterparties attributable to the Company's ownership interests was approximately $3 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, as further described in Note 12, Segment Reporting, to the Company's 2016 Form 10-K. However, such regulated utility counterparties can be impacted by changes in government regulations, which the Company is unable to predict.

- Definition

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 (Notes)

3 Months Ended

Mar. 31, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

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 Company's 2016 Form 10-K.

Energy-Related Commodities

As of March 31, 2017, the Company had energy-related derivative instruments extending through 2020. At March 31, 2017, these contracts were not designated as cash flow or fair value hedges.

Interest Rate Swaps

As of March 31, 2017, the Company had interest rate derivative instruments on non-recourse debt extending through 2036, most 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 commodity:



		Total Volume
		March 31, 2017		December 31, 2016
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		3
Interest	Dollars	$	2,028	$	2,070

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				Derivative Liabilities
	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	—	$	—	$	20	$	26
Interest rate contracts long-term	2		1		29		39
Total Derivatives Designated as Cash Flow Hedges	2		1		49		65
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	—		—		7		5
Interest rate contracts long-term	—		—		10		5
Commodity contracts current	1		2		1		1
Commodity contracts long-term	—		—		1		—
Total Derivatives Not Designated as Cash Flow Hedges	1		2		19		11
Total Derivatives	$	3	$	3	$	68	$	76

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 March 31, 2017 and December 31, 2016, there was no outstanding collateral paid or received. The following tables summarize the offsetting of derivatives by the counterparty master agreement level as of March 31, 2017 and December 31, 2016:



As of March 31, 2017	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	1		$	—		$	1
Derivative liabilities	(2		)	—			(2		)
Total commodity contracts	(1		)	—			(1		)
Interest rate contracts:
Derivative assets	2			(1		)	1
Derivative liabilities	(66		)	1			(65		)
Total interest rate contracts	(64		)	—			(64		)
Total derivative instruments	$	(65	)	$	—		$	(65	)



As of December 31, 2016	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	2		$	—		$	2
Derivative liabilities	$	(1	)	$	—		$	(1	)
Total commodity contracts	1			—			1
Interest rate contracts:
Derivative assets	1			(1		)	—
Derivative liabilities	(75		)	1			(74		)
Total interest rate contracts	(74		)	—			(74		)
Total derivative instruments	$	(73	)	$	—		$	(73	)

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:



		Three months ended March 31,
		2017			2016
	(In millions)
Accumulated OCL beginning balance		$	(86	)	$	(99	)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts		5			4
Mark-to-market of cash flow hedge accounting contracts		2			(54		)
Accumulated OCL ending balance		(79		)	(149		)
Accumulated OCL attributable to noncontrolling interests		(3		)	(4		)
Accumulated OCL attributable to NRG Yield LLC		$	(76	)	$	(145	)
Losses expected to be realized from OCL during the next 12 months		$	(18	)

Amounts reclassified from accumulated OCL into income and amounts recognized in income from the ineffective portion of cash flow hedges are recorded to interest expense. There was no ineffectiveness for the three months ended March 31, 2017 and 2016.

Accounting guidelines require a high degree of correlation between the derivative and the hedged item throughout the period in order to qualify as a cash flow hedge. As of December 31, 2016, the Company's regression analysis for Viento Funding II interest rate swaps, while positively correlated, did not meet the required threshold for cash flow hedge accounting. As a result, the Company de-designated the Viento Funding II cash flow hedges as of December 31, 2016, and will prospectively mark these derivatives to market through the income statement.

Impact of Derivative Instruments on the Statements of Income

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 March 31, 2017 and 2016, the impact to the consolidated statements of income was a gain of $2 million and a loss of $7 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 income for these contracts.

See Note 4, Fair Value of Financial Instruments, for a discussion regarding concentration of credit risk.

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 45
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6441202&loc=d3e80720-113993

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=64837297&loc=SL5624171-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
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-URI http://asc.fasb.org/extlink&oid=64837297&loc=d3e41620-113959

Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-SubTopic 10
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-Paragraph 4B
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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Reference 8: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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Reference 9: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 815
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-Paragraph 1A
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Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 11: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Name Accounting Standards Codification
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Reference 14: http://www.xbrl.org/2003/role/presentationRef
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Reference 15: http://www.xbrl.org/2003/role/presentationRef
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-Subparagraph (SX 210.4-08.(n))
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+ Details

Long-term Debt

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Long-term Debt

This footnote should be read in conjunction with the complete description under Note 10, Long-term Debt, to the Company's 2016 Form 10-K. Long-term debt consisted of the following:



	March 31, 2017			December 31, 2016			March 31, 2017, interest rate % ^(a)	Letters of Credit Outstanding at March 31, 2017
	(In millions, except rates)
Long-term debt - affiliate, due 2019	$	337		$	337		3.580
Long-term debt - affiliate, due 2020	281			281			3.325
2024 Senior Notes	500			500			5.375
2026 Senior Notes	350			350			5.000
Project-level debt:
Agua Caliente Borrower 2, due 2038	41			—			5.430	17
Alpine, due 2022	144			145			L+1.750	37
Alta Wind I, lease financing arrangement, due 2034	242			242			7.015	16
Alta Wind II, lease financing arrangement, due 2034	191			191			5.696	27
Alta Wind III, lease financing arrangement, due 2034	198			198			6.067	27
Alta Wind IV, lease financing arrangement, due 2034	128			128			5.938	19
Alta Wind V, lease financing arrangement, due 2035	206			206			6.071	30
Alta Realty Investments, due 2031	31			31			7.000	—
Alta Wind Asset Management, due 2031	18			18			L+2.375	—
Avra Valley, due 2031	56			57			L+1.750	3
Blythe, due 2028	19			19			L+1.625	2
Borrego, due 2025 and 2038	69			69			L+ 2.500/5.650	5
CVSR, due 2037	757			771			2.339 - 3.775	—
CVSR Holdco Notes, due 2037	194			199			4.680	13
El Segundo Energy Center, due 2023	414			443			L+1.625 - L+2.250	82
Energy Center Minneapolis, due 2017 and 2025	94			96			5.950 -7.250	—
Energy Center Minneapolis Series D Notes, due 2031	125			125			3.550	—
Kansas South, due 2031	30			30			L+2.000	4
Laredo Ridge, due 2028	98			100			L+1.875	10
Marsh Landing, due 2017 and 2023	361			370			L+1.750 - L+1.875	37
Apple I LLC projects and related subsidiaries financing agreement, due 2030	27			27			6.000	—
Roadrunner, due 2031	37			37			L+1.625	5
South Trent Wind, due 2020	57			57			L+1.625	10
TA High Desert, due 2020 and 2032	49			49			L+2.500/5.150	—
Tapestry, due 2021	168			172			L+1.625	20
Utah Solar Portfolio, due 2022	287			287			L+2.625	11
Viento, due 2023	178			178			L+2.750	27
Walnut Creek, due 2023	303			310			L+1.625	52
WCEP Holdings, due 2023	46			46			L+3.000	—
Subtotal project-level debt:	4,568			4,601
Total debt	6,036			6,069
Less current maturities	(296		)	(291		)
Less net debt issuance costs	(61		)	(62		)
Total long-term debt	$	5,679		$	5,716

^(a) As of March 31, 2017, L+ equals 3 month LIBOR plus x%, except for the Alpine term loan, Marsh Landing term loan, Utah Solar Portfolio, Viento, Walnut Creek term loan, and NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, where L+ equals 1 month LIBOR plus x% and Kansas South, where L+ equals 6 month LIBOR plus x%.

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 March 31, 2017, 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 three months ended March 31, 2017.

Segment Reporting

3 Months Ended

Mar. 31, 2017

Segment Reporting [Abstract]

Segment Reporting

The Company’s segment structure reflects how management currently operates and allocates resources. The Company's businesses are primarily 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 March 31, 2017
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	75		$	99		$	44		$	—		$	218
Cost of operations	22			32			30			—			84
Depreciation and amortization	24			46			5			—			75
General and administrative	—			—			—			4			4
Acquisition-related transaction and integration costs	—			—			—			1			1
Operating income (loss)	29			21			9			(5		)	54
Equity in earnings of unconsolidated affiliates	3			16			—			—			19
Other income, net	—			1			—			—			1
Interest expense	(12		)	(40		)	(3		)	(18		)	(73		)
Net Income (Loss)	$	20		$	(2	)	$	6		$	(23	)	$	1
Total Assets	$	1,937		$	5,901		$	431		$	97		$	8,366



	Three months ended March 31, 2016
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	79		$	111		$	44		$	—		$	234
Cost of operations	23			33			29			—			85
Depreciation and amortization	20			49			5			—			74
General and administrative	—			—			—			2			2
Operating income (loss)	36			29			10			(2		)	73
Equity in earnings of unconsolidated affiliates	3			1			—			—			4
Interest expense	(11		)	(42		)	(2		)	(16		)	(71		)
Net Income (Loss)	$	28		$	(12	)	$	8		$	(18	)	$	6

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8595-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 35
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8984-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e9054-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 29
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8864-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8906-108599

+ Details

Related Party Transactions	3 Months Ended
Related Party Transactions	Mar. 31, 2017
Related Party Transactions [Abstract]
Related Party Transactions Disclosure	Related Party Transactions In addition to the transactions and relationships described elsewhere in these notes to the consolidated financial statements, NRG and certain subsidiaries of NRG provide services to the Company and its project entities. Amounts due to NRG subsidiaries are recorded as accounts payable - affiliate and amounts due to the Company from NRG or its subsidiaries are recorded as accounts receivable - affiliate in the Company's balance sheet. PPA by and between Elbow Creek and NRG In October 2015, Elbow Creek, the Company's subsidiary in the Renewables segment, entered into a PPA with NRG Power Marketing for the sale of energy and environmental attributes with the effective date of November 1, 2015, and expiring on October 31, 2022. Elbow Creek generated $3 million of revenue during the three months ended March 31, 2017 and 2016, respectively. Energy Marketing Services Agreement by and between NRG Energy Center Minneapolis LLC and NRG NRG Energy Center Minneapolis LLC, or NRG Minneapolis, a subsidiary of the Company is party to an Energy Marketing Services Agreement with NRG Power Marketing, a wholly-owned subsidiary of NRG. Under the agreement, NRG Power Marketing procures fuel and fuel transportation for the operation of the Minneapolis generating facility. For the three months ended March 31, 2017 and 2016, NRG Minneapolis purchased $4 million and $3 million, respectively, of natural gas from NRG Power Marketing. Operation and Maintenance (O&M) Services Agreements by and between Thermal Entities and NRG Certain thermal entities which are wholly-owned subsidiaries of the Company are party to a Plant O&M Services Agreement with NRG, pursuant to which NRG provides 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. Total fees incurred under the agreements were $8 million and $7 million for the three months ended March 31, 2017 and 2016, respectively. There was a balance of $19 million and $20 million due to NRG in accounts payable — affiliate as of March 31, 2017 and December 31, 2016, respectively. As of March 31, 2017, $13 million of the balance was recorded in the current liabilities of the consolidated balance sheet and $6 million was recorded in long term liabilities of the consolidated balance sheet. Administrative Services Agreement by and between Marsh Landing and NRG West Coast LLC On December 19, 2016, Marsh Landing entered into an administrative services agreement with NRG West Coast LLC, a wholly owned subsidiary of NRG. The administrative services agreement was previously between Marsh Landing and GenOn Energy Services, LLC, a wholly-owned subsidiary of NRG. The Company reimbursed costs under this agreement of $3 million and $2 million for the three months ended March 31, 2017 and 2016, respectively. There was a balance of $1 million due to NRG West Coast LLC in accounts payable — affiliate as of March 31, 2017. Administrative Services Agreement by and between the Company and NRG Renew Operations & Maintenance LLC Various wholly-owned subsidiaries of the Company in the Renewables segment are party to an administrative services agreement with NRG Renew Operations and Maintenance LLC, or RENOM, a wholly-owned subsidiary of NRG, which provides O&M services on behalf of these entities. The Company incurred total expenses for these services in the amount of $3 million and $2 million for the three months ended March 31, 2017 and 2016, respectively. There was a balance of $3 million and $5 million due to RENOM as of March 31, 2017 and December 31, 2016, respectively. Management Services Agreement by and between the Company and NRG NRG provides the Company with various operation, 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 March 31, 2017, the base management fee was approximately $8 million per year, subject to an inflation-based adjustment annually at an inflation factor based on the year-over-year U.S. consumer price index. The fee is also subject to adjustments following the consummation of acquisitions and as a result of a change in the scope of services provided under the Management Services Agreement. Costs incurred under this agreement were $2 million for the three months ended March 31, 2017 and 2016, which included certain direct expenses incurred by NRG on behalf of the Company in addition to the base management fee. There was a balance of $2 million due to NRG in accounts payable — affiliate as of March 31, 2017.

Condensed Consolidating Financial Information Condensed Consolidating Financial Information

3 Months Ended

Mar. 31, 2017

Condensed Consolidating Financial Information Disclosure [Abstract]

Condensed Financial Statements [Text Block]

Condensed Consolidating Financial Information

As of March 31, 2017, Yield Operating LLC had outstanding $500 million of the 2024 Senior Notes and $350 million of the 2026 Senior Notes, collectively Senior Notes, as described in Note 6, Long-term Debt, These Senior Notes are guaranteed by NRG Yield LLC, as well as certain of the Company's subsidiaries, or guarantor subsidiaries. These guarantees are both joint and several. The non-guarantor subsidiaries include the rest of the Company's subsidiaries, including those that are subject to project financing.

Unless otherwise noted below, each of the following guarantor subsidiaries fully and unconditionally guaranteed the Senior Notes as of March 31, 2017:

NRG Yield LLC

Alta Wind 1-5 Holding Company, LLC

Alta Wind Company, LLC

NRG Energy Center Omaha Holdings LLC

NRG Energy Center Omaha LLC

NYLD Fuel Cell Holdings LLC

UB Fuel Cell, LLC

NRG South Trent Holdings LLC

NRG Yield DGPV Holding LLC

NRG Yield RPV Holding LLC

Yield Operating LLC conducts its business through and derives its income from its subsidiaries. Therefore, its ability to make required payments with respect to its indebtedness and other obligations depends on the financial results and condition of its subsidiaries and Yield Operating LLC's ability to receive funds from its subsidiaries. There are no restrictions on the ability of any of the guarantor subsidiaries to transfer funds to Yield Operating LLC. However, there may be restrictions for certain non-guarantor subsidiaries.

The following condensed consolidating financial information presents the financial information of NRG Yield LLC, Yield Operating LLC, the issuer of the 2024 Senior Notes and the 2026 Senior Notes, the guarantor subsidiaries and the non-guarantor subsidiaries in accordance with Rule 3-10 under the SEC Regulation S-X. The financial information may not necessarily be indicative of results of operations or financial position had the guarantor subsidiaries or non-guarantor subsidiaries operated as independent entities.

In this presentation, NRG Yield LLC consists of parent company operations. Guarantor subsidiaries and non-guarantor subsidiaries of NRG Yield LLC are reported on an equity basis. For companies acquired, the fair values of the assets and liabilities acquired have been presented on a push-down accounting basis. As described in Note 1, Nature of Business, the Company completed the acquisition of the March 2017 Drop Down Assets and CVSR Drop Down Asset from NRG on March 27, 2017 and September 1, 2016, respectively. 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. Accordingly, the Company prepared its condensed consolidating financial statements to reflect the transfers as if they had taken place from the beginning of the financial statements period.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF INCOME

For the Three Months Ended March 31, 2017

(Unaudited)



	NRG Yield LLC		Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations^(a)			Consolidated
	(In millions)
Operating Revenues
Total operating revenues	$	—	$	5		$	213		$	—		$	—		$	218
Operating Costs and Expenses
Cost of operations	—		4			80			—			—			84
Depreciation and amortization	—		1			74			—			—			75
General and administrative	—		—			—			4			—			4
Acquisition-related transaction and integration costs	—		—			—			1			—			1
Total operating costs and expenses	—		5			154			5			—			164
Operating Income (Loss)	—		—			59			(5		)	—			54
Other Income (Expense)
Equity in earnings (losses) of consolidated affiliates	10		(11		)	—			23			(22		)	—
Equity in earnings of unconsolidated affiliates	—		2			16			1			—			19
Other income, net	—		—			1			—			—			1
Interest expense	—		—			(55		)	(18		)	—			(73		)
Total other income (expense), net	10		(9		)	(38		)	6			(22		)	(53		)
Net Income (Loss)	10		(9		)	21			1			(22		)	1
Less: Net loss attributable to noncontrolling interests	—		—			(1		)	(9		)	1			(9		)
Net Income (Loss) Attributable to NRG Yield LLC	$	10	$	(9	)	$	22		$	10		$	(23	)	$	10

^(a) All significant intercompany transactions have been eliminated in consolidation.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

For the Three Months Ended March 31, 2017

(Unaudited)



	NRG Yield LLC		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations^(a)			Consolidated
	(In millions)
Net Income (Loss)	$	10	$	(9	)	$	21		$	1		$	(22	)	$	1
Other Comprehensive Income
Unrealized gain on derivatives	7		—			6			7			(13		)	7
Other comprehensive income	7		—			6			7			(13		)	7
Comprehensive Income (Loss)	17		(9		)	27			8			(35		)	8
Less: Comprehensive loss attributable to noncontrolling interests	—		—			(1		)	(9		)	1			(9		)
Comprehensive Income (Loss) Attributable to NRG Yield LLC	$	17	$	(9	)	$	28		$	17		$	(36	)	$	17

^(a) All significant intercompany transactions have been eliminated in consolidation.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

March 31, 2017

(Unaudited)



	NRG Yield LLC		Other Guarantor Subsidiaries		Non-Guarantor Subsidiaries		NRG Yield Operating LLC (Note Issuer)		Eliminations^(a)			Consolidated
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	93	$	—	$	117	$	—	$	—		$	210
Restricted cash	—		—		106		—		—			106
Accounts receivable — trade	—		2		80		—		—			82
Accounts receivable — affiliate	3		—		—		—		—			3
Inventory	—		1		39		—		—			40
Derivative instruments	—		—		1		—		—			1
Notes receivable	—		—		15		—		—			15
Prepayments and other current assets	—		—		19		—		—			19
Total current assets	96		3		377		—		—			476
Net property, plant and equipment	—		58		5,332		—		—			5,390
Other Assets
Investment in consolidated subsidiaries	1,699		483		—		3,134		(5,316		)	—
Equity investments in affiliates	—		177		610		367		—			1,154
Notes receivable	—		—		10		—		—			10
Intangible assets, net	—		55		1,213		—		—			1,268
Derivative instruments	—		—		2		—		—			2
Other non-current assets	—		—		65		1		—			66
Total other assets	1,699		715		1,900		3,502		(5,316		)	2,500
Total Assets	$	1,795	$	776	$	7,609	$	3,502	$	(5,316	)	$	8,366

^(a) All significant intercompany transactions have been eliminated in consolidation.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

March 31, 2017

(Continued)



	NRG Yield LLC			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations^(a)			Consolidated
LIABILITIES AND MEMBERS' EQUITY	(In millions)
Current Liabilities
Current portion of long-term debt — external	$	—		$	—		$	296		$	—		$	—		$	296
Accounts payable	—			1			25			—			—			26
Accounts payable — affiliate	—			5			23			22			—			50
Derivative instruments	—			—			28			—			—			28
Accrued expenses and other current liabilities	—			1			42			11			—			54
Total current liabilities	—			7			414			33			—			454
Other Liabilities
Long-term debt — external	—			—			4,222			839			—			5,061
Long-term debt — affiliate	—			—			—			618			—			618
Accounts payable — affiliate	—			—			6			—			—			6
Derivative instruments	—			—			40			—			—			40
Other non-current liabilities	—			—			79			—			—			79
Total non-current liabilities	—			—			4,347			1,457			—			5,804
Total Liabilities	—			7			4,761			1,490			—			6,258
Commitments and Contingencies
Members' Equity
Contributed capital	1,865			845			2,856			1,957			(5,658		)	1,865
Retained earnings (accumulated deficit)	6			(74		)	11			(182		)	245			6
Accumulated other comprehensive loss	(76		)	(2		)	(81		)	(76		)	159			(76		)
Noncontrolling interest	—			—			62			313			(62		)	313
Total Members' Equity	1,795			769			2,848			2,012			(5,316		)	2,108
Total Liabilities and Members’ Equity	$	1,795		$	776		$	7,609		$	3,502		$	(5,316	)	$	8,366

^(a) All significant intercompany transactions have been eliminated in consolidation.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS

For the Three Months ended March 31, 2017

(Unaudited)



	NRG Yield LLC			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Consolidated
	(In millions)
Net Cash Provided by (Used in) Operating Activities	$	—		$	1		$	109		$	(49	)	$	61
Cash Flows from Investing Activities
Intercompany transactions between Yield LLC and subsidiaries	(65		)	—			—			65			—
Acquisition of Drop Down Assets	—			—			—			(131		)	(131		)
Capital expenditures	—			—			(4		)	—			(4		)
Increase in restricted cash	—			—			59			—			59
Decrease in notes receivable	—			—			4			—			4
Return of investment from unconsolidated affiliates	—			3			—			13			16
Net investments in unconsolidated affiliates	—			(3		)	(4		)	—			(7		)
Net Cash (Used in) Provided by Investing Activities	(65		)	—			55			(53		)	(63		)
Cash Flows from Financing Activities
Transfer of funds under intercompany cash management arrangement	(5		)	(1		)	—			6			—
Net contributions from noncontrolling interests	—			—			—			14			14
Net distributions and return of capital to NRG prior to the acquisition of Drop Down Assets	—			—			(38		)	—			(38		)
(Payments of) proceeds from distributions	(53		)	—			(82		)	82			(53		)
Payment of debt issuance costs	—			—			(3		)	—			(3		)
Proceeds from Issuance of Class C units	5			—			—			—			5
Proceeds from the issuance of long-term debt — external	—			—			41			—			41
Payments for long-term debt	—			—			(75		)	—			(75		)
Net Cash (Used in) Provided by Financing Activities	(53		)	(1		)	(157		)	102			(109		)
Net (Decrease) Increase in Cash and Cash Equivalents	(118		)	—			7			—			(111		)
Cash and Cash Equivalents at Beginning of Period	211			—			110			—			321
Cash and Cash Equivalents at End of Period	$	93		$	—		$	117		$	—		$	210

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF INCOME

For the Three Months Ended March 31, 2016

(Unaudited)



	NRG Yield LLC		Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations ^(a)			Consolidated
	(In millions)
Operating Revenues
Total operating revenues	$	—	$	5		$	229		$	—		$	—		$	234
Operating Costs and Expenses
Cost of operations	—		3			82			—			—			85
Depreciation and amortization	—		1			73			—			—			74
General and administrative	—		—			—			2			—			2
Total operating costs and expenses	—		4			155			2			—			161
Operating Income (Loss)	—		1			74			(2		)	—			73
Other (Expense) Income
Equity in income (losses) of consolidated affiliates	17		(7		)	—			21			(31		)	—
Equity in earnings (losses) of unconsolidated affiliates	—		2			(1		)	3			—			4
Interest expense	—		—			(55		)	(16		)	—			(71		)
Total other income (expense), net	17		(5		)	(56		)	8			(31		)	(67		)
Net Income (Loss)	17		(4		)	18			6			(31		)	6
Less: Net loss attributable to noncontrolling interests	—		—			—			(11		)	—			(11		)
Net Income (Loss) Attributable to NRG Yield LLC	$	17	$	(4	)	$	18		$	17		$	(31	)	$	17

^(a) All significant intercompany transactions have been eliminated in consolidation.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

December 31, 2016

(Unaudited)



	NRG Yield LLC		Other Guarantor Subsidiaries		Non-Guarantor Subsidiaries		NRG Yield Operating LLC (Note Issuer)		Eliminations^(a)			Consolidated
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	211	$	—	$	110	$	—	$	—		$	321
Restricted cash	—		—		165		—		—			165
Accounts receivable — trade	—		2		90		—		—			92
Accounts receivable — affiliate	—		—		1		—		—			1
Inventory	—		2		37		—		—			39
Derivative instruments	—		—		2		—		—			2
Notes receivable	—		—		16		—		—			16
Prepayments and other current assets	—		—		19		1		—			20
Total current assets	211		4		440		1		—			656

Net property, plant and equipment	—		59		5,401		—		—			5,460
Other Assets
Investment in consolidated subsidiaries	1,780		527		—		3,212		(5,519		)	—
Equity investments in affiliates	—		171		600		381		—			1,152
Notes receivable	—		—		14		—		—			14
Intangible assets, net	—		56		1,230		—		—			1,286
Derivative instruments	—		—		1		—		—			1
Other non-current assets	—		—		50		1		—			51
Total other assets	1,780		754		1,895		3,594		(5,519		)	2,504
Total Assets	$	1,991	$	817	$	7,736	$	3,595	$	(5,519	)	$	8,620

^(a) All significant intercompany transactions have been eliminated in consolidation.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

December 31, 2016

(Continued)



	NRG Yield LLC			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations^(a)			Consolidated
LIABILITIES AND MEMBERS' EQUITY	(In millions)
Current Liabilities
Current portion of long-term debt — external	$	—		$	—		$	291		$	—		$	—		$	291
Accounts payable	—			2			18			3			—			23
Accounts payable — affiliate	—			7			15			18			—			40
Derivative instruments	—			—			32			—			—			32
Accrued expenses and other current liabilities	—			1			60			24			—			85
Total current liabilities	—			10			416			45			—			471
Other Liabilities
Long-term debt — external	—			—			4,259			839			—			5,098
Long-term debt — affiliate	—			—			—			618			—			618
Accounts payable — affiliate	—			—			9			—			—			9
Derivative instruments	—			—			44			—			—			44
Other non-current liabilities	—			—			76			—			—			76
Total non-current liabilities	—			—			4,388			1,457			—			5,845
Total Liabilities	—			10			4,804			1,502			—			6,316
Commitments and Contingencies
Members' Equity
Contributed capital	1,995			874			2,920			1,971			(5,765		)	1,995
Retained earnings (Accumulated deficit)	79			(65		)	35			(108		)	138			79
Accumulated other comprehensive loss	(83		)	(2		)	(87		)	(83		)	172			(83		)
Noncontrolling Interest	—			—			64			313			(64		)	313
Total Members' Equity	1,991			807			2,932			2,093			(5,519		)	2,304
Total Liabilities and Members’ Equity	$	1,991		$	817		$	7,736		$	3,595		$	(5,519	)	$	8,620

^(a) All significant intercompany transactions have been eliminated in consolidation.

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS

For the Three Months Ended March 31, 2016

(Unaudited)



	NRG Yield LLC			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Consolidated
	(In millions)
Net Cash Provided by (Used in) Operating Activities	$	—		$	1		$	99		$	(11	)	$	89
Cash Flows from Investing Activities
Intercompany transactions from Yield LLC to subsidiaries	12			40			—			(52		)	—
Capital expenditures	—			—			(7		)	—			(7		)
Decrease in restricted cash	—			—			23			—			23
Decrease in notes receivable	—			—			4			—			4
Return of investment from unconsolidated affiliates	—			—			—			8			8
Net investments in unconsolidated affiliates	—			(40		)	—			(11		)	(51		)
Other	—			—			—			2			2
Net Cash Provided by (Used in) Investing Activities	12			—			20			(53		)	(21		)
Cash Flows from Financing Activities
Transfer of funds under intercompany cash management arrangement	24			(1		)	—			(23		)	—
Net contributions from noncontrolling interests	—			—			—			10			10
Net distributions and return of capital to NRG prior to the acquisition of Drop Down Assets	—			—			(11		)	—			(11		)
(Payments of) proceeds from distributions	(41		)	—			(71		)	67			(45		)
Proceeds from the revolving credit facility	—			—			—			50			50
Payments for the revolving credit facility	—			—			—			(40		)	(40		)
Payments for long-term debt	—			—			(67		)	—			(67		)
Net Cash (Used in) Provided by Financing Activities	(17		)	(1		)	(149		)	64			(103		)
Net (Decrease) Increase in Cash and Cash Equivalents	(5		)	—			(30		)	—			(35		)
Cash and Cash Equivalents at Beginning of Period	15			—			95			—			110
Cash and Cash Equivalents at End of Period	$	10		$	—		$	65		$	—		$	75

Commitments and Contingencies (Notes)	3 Months Ended
Commitments and Contingencies (Notes)	Mar. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure [Text Block]	Contingencies 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. 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.

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

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Distributions [Policy Text Block]

Distributions

The following table lists the distributions paid on NRG Yield LLC's Class A, B, C and D units during the three months ended March 31, 2017:



	First Quarter 2017
Distributions per Class A, B, C and D unit	$	0.26

On April 25, 2017, the Company declared a distribution on its Class A, Class B, Class C and Class D units of $0.27 per unit payable on June 15, 2017 to unit holders of record as of June 1, 2017.

Reclassifications

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

Use of Estimates

The preparation of consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions.

Recent Accounting Developments

Noncontrolling Interest Disclosure [Text Block]

Noncontrolling Interests

The following table reflects the changes in the Company's noncontrolling interest balance:



	(In millions)
Balance as of December 31, 2016	313
Capital contributions from tax equity investors, net of distributions	14
Comprehensive income	(9		)
Distributions to NRG for its 25% interest in TE Holdco	(5		)
Balance as of March 31, 2017	$	313

Segment Reporting Segment Reporting (Policies)	3 Months Ended
Segment Reporting Segment Reporting (Policies)	Mar. 31, 2017
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 primarily 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)

3 Months Ended

Mar. 31, 2017

Nature of Business Disclosure [Abstract]

IPO of NRG Yield [Table Text Block]

The following table represents the structure of the Company as of March 31, 2017:

Schedule of Ownership [Table Text Block]

As of March 31, 2017, 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
CVSR	100	%	250	Pacific Gas and Electric	2038
Desert Sunlight 250	25	%	63	Southern California Edison	2035
Desert Sunlight 300	25	%	75	Pacific Gas and Electric	2040
Kansas South	100	%	20	Pacific Gas and Electric	2033
Roadrunner	100	%	20	El Paso Electric	2031
TA High Desert	100	%	20	Southern California Edison	2033
Utah Solar Portfolio^(e)	50	%	265	PacifiCorp	2036
			921
Distributed Solar
Apple I LLC Projects	100	%	9	Various	2032
AZ DG Solar Projects	100	%	5	Various	2025 - 2033
			14
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)}	74.3	%	16	Corn Belt Power Cooperative	2027
Elbow Creek ^{(b) (f)}	75	%	92	NRG Power Marketing LLC	2022
Elkhorn Ridge ^{(b) (f)}	50.3	%	41	Nebraska Public Power District	2029
Forward ^{(b) (f)}	75	%	22	Constellation NewEnergy, Inc.	2017
Goat Wind ^{(b) (f)}	74.9	%	113	Dow Pipeline Company	2025
Hardin ^{(b) (f)}	74.3	%	11	Interstate Power and Light Company	2027
Laredo Ridge	100	%	80	Nebraska Public Power District	2031
Lookout ^{(b) (f)}	75	%	29	Southern Maryland Electric Cooperative	2030
Odin ^{(b) (f)}	74.9	%	15	Missouri River Energy Services	2028
Pinnacle	100	%	55	Maryland Department of General Services and University System of Maryland	2031
San Juan Mesa ^{(b) (f)}	56.3	%	68	Southwestern Public Service Company	2025
Sleeping Bear ^{(b) (f)}	75	%	71	Public Service Company of Oklahoma	2032
South Trent	100	%	101	AEP Energy Partners	2029
Spanish Fork ^{(b) (f)}	75	%	14	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)}	74.9	%	121	Southwestern Public Service Company	2027



Projects	Percentage Ownership		Net Capacity (MW)^(a)	Offtake Counterparty	Expiration
			1,999
Thermal
Thermal equivalent MWt ^(c)	100	%	1,319	Various	Various
NRG Dover Energy Center LLC	100	%	103	NRG Power Marketing LLC	2018
Thermal generation	100	%	20	Various	Various
			1,442
Total net capacity (excluding equivalent MWt)^(d)			5,002

^(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 March 31, 2017.

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

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

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

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Schedule of Accumulated Depreciation and Amortization [Table Text Block]



	March 31, 2017		December 31, 2016
	(In millions)
Property, Plant and Equipment Accumulated Depreciation	$	1,025	$	951
Intangible Assets Accumulated Amortization	181		163

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

Distributions

The following table lists the distributions paid on NRG Yield LLC's Class A, B, C and D units during the three months ended March 31, 2017:



	First Quarter 2017
Distributions per Class A, B, C and D unit	$	0.26

On April 25, 2017, the Company declared a distribution on its Class A, Class B, Class C and Class D units of $0.27 per unit payable on June 15, 2017 to unit holders of record as of June 1, 2017.

Reclassifications

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

Schedule of Change in Noncontrolling Interest [Table Text Block]

The following table reflects the changes in the Company's noncontrolling interest balance:



	(In millions)
Balance as of December 31, 2016	313
Capital contributions from tax equity investors, net of distributions	14
Comprehensive income	(9		)
Distributions to NRG for its 25% interest in TE Holdco	(5		)
Balance as of March 31, 2017	$	313

Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2017

March 2017 Drop Down Assets [Member]

Schedule of Equity Method Investments [Line Items]

Schedule of Variable Interest Entities [Table Text Block]

The following is a summary of assets and liabilities transferred in connection with the acquisition of the March 2017 Drop Down Assets as of March 27, 2017:



	(In millions)
Assets:
Cash	$	6
Equity investment in projects	456
Total assets acquired	462
Liabilities:
Debt (Current and non-current) ^(a)	320
Other current and non-current liabilities	3
Total liabilities assumed	323
Net assets acquired	$	139

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 March 31, 2017 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	$	228
Granite Mountain Holdings, LLC	81
Iron Springs Holdings, LLC	54
NRG DGPV Holdco 1 LLC	73
NRG DGPV Holdco 2 LLC	34
NRG RPV Holdco 1 LLC	70
GenConn Energy LLC	104

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 March 31, 2017:



(In millions)	NRG Wind TE Holdco		Alta Wind TE Holdco		Spring Canyon
Other current and non-current assets	$	193	$	18	$	4
Property, plant and equipment	435		455		99
Intangible assets	2		271		—
Total assets	630		744		103
Current and non-current liabilities	210		8		6
Total liabilities	210		8		6
Noncontrolling interest	141		106		66
Net assets less noncontrolling interests	$	279	$	630	$	31

- Definition

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)

3 Months Ended

Mar. 31, 2017

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

Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) [Table Text Block]

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



		Three months ended March 31,
		2017			2016
	(In millions)
Accumulated OCL beginning balance		$	(86	)	$	(99	)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts		5			4
Mark-to-market of cash flow hedge accounting contracts		2			(54		)
Accumulated OCL ending balance		(79		)	(149		)
Accumulated OCL attributable to noncontrolling interests		(3		)	(4		)
Accumulated OCL attributable to NRG Yield LLC		$	(76	)	$	(145	)
Losses expected to be realized from OCL during the next 12 months		$	(18	)

Estimated carrying values and fair values of the Company's recorded financial instruments

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 March 31, 2017				As of December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Assets:
Notes receivable, including current portion	$	25	$	25	$	30	$	30
Liabilities:
Long-term debt — affiliate	618		613		618		608
Long-term debt — external, including current portion	$	5,418	$	5,413	$	5,451	$	5,435

Fair Value, Option, Quantitative Disclosures [Table Text Block]



	As of March 31, 2017				As of December 31, 2016
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	844	$	5,182	$	833	$	5,210

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]



	As of March 31, 2017		As of December 31, 2016
	Fair Value ^(a)		Fair Value ^(a)		Fair Value ^(a)
(In millions)	Level 2		Level 1		Level 2
Derivative assets:
Commodity contracts	$	1	$	1	$	1
Interest rate contracts	2		—		1
Total assets	3		1		2
Derivative liabilities:
Commodity contracts	2		—		1
Interest rate contracts	66		—		75
Total liabilities	$	68	$	—	$	76

- Definition

Tabular disclosure of the application of the fair value option for measurement and reporting of eligible financial assets and liabilities (as defined), as well as certain other eligible items (as defined) included in the statement of financial position, whether such option is elected for a single eligible item or a group of similar eligible items and is in addition to other disclosures concerning fair value which the company may be required to provide. Such disclosure might be expected to include: (1) for items included in the statement of financial position: (a) for each line item in the statement of financial position that includes an item or items for which the fair value option has been elected, provide the aggregate carrying amount of ineligible items included in each line item in the balance sheet, if any; (b) the difference between the aggregate fair value and the aggregate unpaid principal balance (assuming contractual principal amounts and fair value option elected) of: (i) loans and long-term receivables (other than securities otherwise reported at fair value) and (ii) long-term debt instruments; (c) for loans held as assets for which the fair value option has been elected: (i) the aggregate fair value of loans that are 90 days or more past due, (ii) if the policy is to recognize interest income separately from other changes in fair value, the aggregate fair value of loans in nonaccrual status, and (iii) the difference between the aggregate fair value and the aggregate unpaid principal balance for loans that are 90 days or more past due, in nonaccrual status, or both; (2) for items included in the income statement: (a) the amounts of gains and losses from fair value changes included in earnings and in which line in the income statement those gains and losses are reported whether or not combined with gains and losses from items required to be accounted for at fair value; (b) for loans and other receivables held as assets, the estimated amount of gains or losses included in earnings attributable to changes in instrument-specific credit risk; (c) for liabilities with fair values that have been significantly affected during the reporting period by changes in the instrument-specific credit risk, the estimated amount of gains and losses from fair value changes included in earnings that are attributable to changes in the instrument-specific credit risk; and (3) certain other disclosures as required or determined to be provided.

+ References + Details

Accounting for Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2017

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 commodity:



		Total Volume
		March 31, 2017		December 31, 2016
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		3
Interest	Dollars	$	2,028	$	2,070

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				Derivative Liabilities
	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	—	$	—	$	20	$	26
Interest rate contracts long-term	2		1		29		39
Total Derivatives Designated as Cash Flow Hedges	2		1		49		65
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	—		—		7		5
Interest rate contracts long-term	—		—		10		5
Commodity contracts current	1		2		1		1
Commodity contracts long-term	—		—		1		—
Total Derivatives Not Designated as Cash Flow Hedges	1		2		19		11
Total Derivatives	$	3	$	3	$	68	$	76

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



As of March 31, 2017	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	1		$	—		$	1
Derivative liabilities	(2		)	—			(2		)
Total commodity contracts	(1		)	—			(1		)
Interest rate contracts:
Derivative assets	2			(1		)	1
Derivative liabilities	(66		)	1			(65		)
Total interest rate contracts	(64		)	—			(64		)
Total derivative instruments	$	(65	)	$	—		$	(65	)



As of December 31, 2016	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	2		$	—		$	2
Derivative liabilities	$	(1	)	$	—		$	(1	)
Total commodity contracts	1			—			1
Interest rate contracts:
Derivative assets	1			(1		)	—
Derivative liabilities	(75		)	1			(74		)
Total interest rate contracts	(74		)	—			(74		)
Total derivative instruments	$	(73	)	$	—		$	(73	)

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:



		Three months ended March 31,
		2017			2016
	(In millions)
Accumulated OCL beginning balance		$	(86	)	$	(99	)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts		5			4
Mark-to-market of cash flow hedge accounting contracts		2			(54		)
Accumulated OCL ending balance		(79		)	(149		)
Accumulated OCL attributable to noncontrolling interests		(3		)	(4		)
Accumulated OCL attributable to NRG Yield LLC		$	(76	)	$	(145	)
Losses expected to be realized from OCL during the next 12 months		$	(18	)

Long-term Debt (Tables)

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Schedule of long-term debt

This footnote should be read in conjunction with the complete description under Note 10, Long-term Debt, to the Company's 2016 Form 10-K. Long-term debt consisted of the following:

Variable Interest Entities Variable Interest Entities - Utah Solar Portfolio (Details) - Utah Portfolio [Member]	Mar. 31, 2017
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%

Variable Interest Entities Variable Interest Entities - Debt Held by Unconsolidated Affiliates (Details) - USD ($) $ in Millions	Mar. 31, 2017	Mar. 27, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Long-term Debt	$ 6,036		$ 6,069
Agua Caliente Borrower 2 [Member]
Schedule of Equity Method Investments [Line Items]
Pro-Rate Share of Debt Held by Unconsolidated Affiliates		$ 135
Agua Caliente [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		16.00%
Long-term Debt	$ 846

Fair Value of Financial Instruments Fair Value of Financial Instruments - Credit Risk and Derivative FV Measurements (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Assets, Measured on Recurring Basis, Valuation Techniques, Impact of Credit Reserve to Fair Value	$ 1
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$ 3,000
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	Mar. 31, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 3	$ 3
Derivative Liability, Fair Value, Gross Liability	68	76
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative, Collateral, Obligation to Return Cash	0	0
Derivative Asset	1
Fair Value of Gross Derivative Assets/(Liabilities), Net	(65)	(73)
Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset	0	0
Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral	(65)	(73)
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	2	1
Derivative Liability, Fair Value, Gross Liability	49	65
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1	2
Derivative Liability, Fair Value, Gross Liability	19	11
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1	2
Derivative Liability, Fair Value, Gross Liability	2	1
Derivative Asset, Fair Value, Gross Liability	0	0
Derivative Asset	1	2
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative Liability	2	1
Fair Value of Gross Derivative Assets/(Liabilities), Net	(1)	1
Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset	0	0
Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral	(1)	1
Interest Rate Contract Current [Member] \| Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	20	26
Interest Rate Contract Current [Member] \| Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	7	5
Interest Rate Contract Non Current [Member] \| Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	2	1
Derivative Liability, Fair Value, Gross Liability	29	39
Interest Rate Contract Non Current [Member] \| Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	10	5
Commodity Contract Current [Member] \| Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1	2
Derivative Liability, Fair Value, Gross Liability	1	1
Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	2	1
Derivative Liability, Fair Value, Gross Liability	66	75
Derivative Asset, Fair Value, Gross Liability	1	1
Derivative Asset	1	0
Derivative Liability, Fair Value, Gross Asset	1	1
Derivative Liability	65	74
Fair Value of Gross Derivative Assets/(Liabilities), Net	(64)	(74)
Derivative Asset Fair Value Gross Liability Net Of Derivative Liability Fair Value Gross Asset	0	0
Derivative Asset, Fair Value, Amount Offset Against Collateral Net Of Derivative Liability, Fair Value, Amount Offset Against Collateral	(64)	(74)
Commodity Contract Non Current [Member] \| Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0
Derivative Liability, Fair Value, Gross Liability	1	0
United States of America, Dollars \| Interest [Member]
Derivatives, Fair Value [Line Items]
Derivative, Notional Amount	2,028	2,070
MMbtu [Member] \| Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Derivative, Notional Amount	$ 2	$ 3

Accounting for Derivative Instruments and Hedging Activities Accounting for Derivative Instruments and Hedging Activities - Impact on Statement of Operations (Details) - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Interest Rate Contract [Member] \| Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized Gain (Loss) on Derivatives	$ 2,000,000	$ 7,000,000
Commodity Contract [Member] \| Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized Gain (Loss) on Derivatives	$ 0