Clearway Energy, Inc. - Quarter Report: 2015 September (Form 10-Q)

Large accelerated filer x

Accelerated filer o

Non-accelerated filer o

Smaller reporting company o

(Do not check if a smaller reporting company)

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q



x		Quarterly report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

		For the Quarterly Period Ended: September 30, 2015

o		Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission File Number: 001-36002

NRG Yield, Inc.

(Exact name of registrant as specified in its charter)



Delaware (State or other jurisdiction of incorporation or organization)		46-1777204 (I.R.S. Employer Identification No.)

211 Carnegie Center, Princeton, New Jersey (Address of principal executive offices)		08540 (Zip Code)

(609) 524-4500

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes o No x

As of October 31, 2015, there were 34,586,250 shares of Class A common stock outstanding, par value $0.01 per share, 42,738,750 shares of Class B common stock outstanding, par value $0.01 per share, 62,784,250 shares of Class C common stock outstanding, par value $0.01 per share, and 42,738,750 shares of Class D common stock outstanding, par value $0.01 per share.

TABLE OF CONTENTS

Index



CAUTIONARY STATEMENT REGARDING FORWARD LOOKING INFORMATION	3
GLOSSARY OF TERMS	4
PART I — FINANCIAL INFORMATION	6
ITEM 1 — FINANCIAL STATEMENTS AND NOTES	6
ITEM 2 — MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	36
ITEM 3 — QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	51
ITEM 4 — CONTROLS AND PROCEDURES	52
PART II — OTHER INFORMATION	53
ITEM 1 — LEGAL PROCEEDINGS	53
ITEM 1A — RISK FACTORS	53
ITEM 2 — UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	53
ITEM 3 — DEFAULTS UPON SENIOR SECURITIES	53
ITEM 4 — MINE SAFETY DISCLOSURES	53
ITEM 5 — OTHER INFORMATION	53
ITEM 6 — EXHIBITS	53
SIGNATURES	54

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q of NRG Yield, Inc., together with its consolidated subsidiaries, or the Company, includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, or the Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended, or the Exchange Act. The words "believes," "projects," "anticipates," "plans," "expects," "intends," "estimates" and similar expressions are intended to identify forward-looking statements. These forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause the Company's actual results, performance and achievements, or industry results, to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. These factors, risks and uncertainties include the factors described under Item 1A — Risk Factors in Part I, Item 1A of the Company's Annual Report on Form 10-K for the year ended December 31, 2014, and the following:


•	The Company's ability to maintain and grow its quarterly dividend;


•	The Company's ability to successfully identify, evaluate and consummate acquisitions from third parties;


•	The Company's ability to acquire assets from NRG;


•	The Company's ability to raise additional capital due to its indebtedness, corporate structure, market conditions or otherwise;

•

Hazards customary to the power production industry and power generation operations such as fuel and electricity price volatility, unusual weather conditions, catastrophic weather-related or other damage to facilities, unscheduled generation outages, maintenance or repairs, unanticipated changes to fuel supply costs or availability due to higher demand, shortages, transportation problems or other developments, environmental incidents, or electric transmission or gas pipeline system constraints and the possibility that the Company may not have adequate insurance to cover losses as a result of such hazards;


•	The Company's ability to operate its businesses efficiently, manage maintenance capital expenditures and costs effectively, and generate earnings and cash flows from its asset-based businesses in relation to its debt and other obligations;


•	The willingness and ability of counterparties to the Company's offtake agreements to fulfill their obligations under such agreements;


•	The Company's ability to enter into contracts to sell power and procure fuel on acceptable terms and prices as current offtake agreements expire;


•	Government regulation, including compliance with regulatory requirements and changes in market rules, rates, tariffs and environmental laws;


•	Operating and financial restrictions placed on the Company and its subsidiaries that are contained in the project-level debt facilities and other agreements of certain subsidiaries and project-level subsidiaries generally, in the NRG Yield Operating LLC revolving credit facility, in the indenture governing the Senior Notes and in the indenture governing the Company's convertible notes; and


•	The Company's ability to borrow additional funds and access capital markets, as well as the Company's substantial indebtedness and the possibility that the Company may incur additional indebtedness going forward.

Forward-looking statements speak only as of the date they were made, and the Company undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The foregoing review of factors that could cause the Company's actual results to differ materially from those contemplated in any forward-looking statements included in this Quarterly Report on Form 10-Q should not be construed as exhaustive.

GLOSSARY OF TERMS

When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below:



2014 Form 10-K		NRG Yield, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2014
2019 Convertible Notes		$345 million aggregate principal amount of 3.50% Convertible Notes due 2019
2020 Convertible Notes		$287.5 million aggregate principal amount of 3.25% Convertible Notes due 2020
Alta TE Holdco		Alta Wind X-XI TE Holdco LLC
Alta Wind Portfolio		Seven wind facilities that total 947 MW located in Tehachapi, California and a portfolio of associated land leases
AOCL		Accumulated Other Comprehensive Loss
ASC		The FASB Accounting Standards Codification, which the FASB established as the source of authoritative U.S. GAAP
ASU		Accounting Standards Updates – updates to the ASC
Buffalo Bear		Buffalo Bear, LLC, the operating subsidiary of Tapestry Wind LLC, which owns the Buffalo Bear project
CAFD		Cash Available For Distribution
COD		Commercial Operations Date
Company		NRG Yield, Inc. together with its consolidated subsidiaries
CVSR		California Valley Solar Ranch
DGPV Holdco		NRG DGPV Holdco 1 LLC
Distributed Solar		Solar power projects, typically less than 20 MW in size, that primarily sell power produced to customers for usage on site, or are interconnected to sell power into the local distribution grid
Drop Down Assets		Collectively, the June 2014 Drop Down Assets and the January 2015 Drop Down Assets
Economic Gross Margin		Energy and capacity revenue, less cost of fuels
El Segundo		NRG West Holdings LLC, the subsidiary of Natural Gas Repowering LLC, which owns the El Segundo Energy Center project
EME		Edison Mission Energy
ERCOT		Electric Reliability Council of Texas, the Independent System Operator and the regional reliability coordinator of the various electricity systems within Texas
EWG		Exempt Wholesale Generator
Exchange Act		The Securities Exchange Act of 1934, as amended
FASB		Financial Accounting Standards Board
FERC		Federal Energy Regulatory Commission
GenConn		GenConn Energy LLC
HLBV		Hypothetical Liquidation at Book Value
IASB		International Accounting Standards Board
ISO		Independent System Operator, also referred to as RTO
January 2015 Drop Down Assets		The Laredo Ridge, Tapestry and Walnut Creek projects, which were acquired by the Company from NRG on January 2, 2015
June 2014 Drop Down Assets		The TA High Desert, Kansas South and El Segundo projects, which were acquired by the Company from NRG on June 30, 2014
Kansas South		NRG Solar Kansas South LLC, the operating subsidiary of NRG Solar Kansas South Holdings LLC, which owns the Kansas South project
Laredo Ridge		Laredo Ridge Wind, LLC, the operating subsidiary of Mission Wind Laredo, LLC, which owns the Laredo Ridge project
LIBOR		London Inter-Bank Offered Rate
Marsh Landing		NRG Marsh Landing LLC, formerly GenOn Marsh Landing LLC
MMBtu		Million British Thermal Units
MW		Megawatt



MWh		Saleable megawatt hour, net of internal/parasitic load megawatt-hour
MWt		Megawatts Thermal Equivalent
NERC		North American Electric Reliability Corporation
Net Exposure		Counterparty credit exposure to NRG Yield, Inc. net of collateral
NOLs		Net Operating Losses
November 2015 Drop Down Assets		75% of the Class B interests of NRG Wind TE Holdco, which owns a portfolio of 12 wind facilities totaling 814 net MW
NRG		NRG Energy, Inc.
NRG Wind TE Holdco		NRG Wind TE Holdco LLC
NRG Yield LLC		The holding company through which the projects are owned by NRG, the holder of Class B and Class D common units, and NRG Yield, Inc., the holder of the Class A and Class C common units
NRG Yield Operating LLC		The holder of the project assets that are owned by NRG Yield LLC
OCI/OCL		Other comprehensive income/loss
Pinnacle		Pinnacle Wind, LLC, the operating subsidiary of Tapestry Wind LLC, which owns the Pinnacle project
PPA		Power Purchase Agreement
PUCT		Public Utility Commission of Texas
PURPA		Public Utility Regulatory Policies Act of 1978
QF		Qualifying Facility under PURPA
ROFO Agreement		Amended and Restated Right of First Offer Agreement between the Company and NRG
RPV Holdco		NRG RPV Holdco 1 LLC
RTO		Regional Transmission Organization
SEC		U.S. Securities and Exchange Commission
Senior Notes		NRG Yield Operating LLC's $500 million of 5.375% unsecured senior notes due 2024
TA High Desert		TA-High Desert LLC, the operating subsidiary of NRG Solar Mayfair LLC, which owns the TA High Desert project
Taloga		Taloga Wind, LLC, the operating subsidiary of Tapestry Wind LLC, which owns the Taloga project
Tapestry		Collection of the Pinnacle, Buffalo Bear and Taloga projects
Thermal Business		The Company's thermal business, which consists of thermal infrastructure assets that provide steam, hot water and/or chilled water, and in some instances electricity, to commercial businesses, universities, hospitals and governmental units
U.S.		United States of America
U.S. GAAP		Accounting principles generally accepted in the U.S.
Utility Scale Solar		Solar power projects, typically 20 MW or greater in size (on an alternating current, or AC, basis), that are interconnected into the transmission or distribution grid to sell power at a wholesale level
VaR		Value at Risk
VIE		Variable Interest Entity
Walnut Creek		NRG Walnut Creek, LLC, the operating subsidiary of WCEP Holdings, LLC, which owns the Walnut Creek project

PART I - FINANCIAL INFORMATION

ITEM 1 — FINANCIAL STATEMENTS

NRG YIELD, INC.

CONSOLIDATED STATEMENTS OF INCOME



	Three months ended September 30,						Nine months ended September 30,
(In millions, except per share amounts)	2015			2014 ^(a)			2015			2014^(a)
Operating Revenues
Total operating revenues	$	209		$	184		$	606		$	497
Operating Costs and Expenses
Cost of operations	69			60			211			173
Depreciation and amortization	50			34			163			112
General and administrative — affiliate	3			3			9			7
Acquisition-related transaction and integration costs	1			2			2			2
Total operating costs and expenses	123			99			385			294
Operating Income	86			85			221			203
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	19			11			29			26
Other income, net	1			1			2			2
Loss on debt extinguishment	(2		)	—			(9		)	—
Interest expense	(62		)	(48		)	(176		)	(109		)
Total other expense, net	(44		)	(36		)	(154		)	(81		)
Income Before Income Taxes	42			49			67			122
Income tax expense	8			10			8			15
Net Income	34			39			59			107
Less: Pre-acquisition net income of Drop Down Assets	—			8			—			33
Net Income Excluding Pre-acquisition Net Income of Drop Down Assets	34			31			59			74
Less: Net income attributable to noncontrolling interests	17			25			37			58
Net Income Attributable to NRG Yield, Inc.	$	17		$	6		$	22		$	16
Earnings Per Share Attributable to NRG Yield, Inc. Class A and Class C Common Stockholders
Weighted average number of Class A common shares outstanding - basic and diluted	35			31			35			25
Weighted average number of Class C common shares outstanding - basic and diluted	63			31			44			25
Earnings per Weighted Average Class A and Class C Common Share - Basic and Diluted	0.18			0.10			0.28			0.31
Dividends Per Class A Common Share	$	0.21		$	0.365		$	0.80		$	1.045
Dividends Per Class C Common Share	$	0.21		N/A			$	0.41		N/A

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

See accompanying notes to consolidated financial statements.

NRG YIELD, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)



	Three months ended September 30,					Nine months ended September 30,
(In millions)	2015			2014 ^(a)		2015			2014 ^(a)
Net Income	$	34		$	39	$	59		$	107
Other Comprehensive Income (Loss), net of tax
Unrealized (loss) gain on derivatives, net of income tax benefit of $9, $2, $13 and $2	(29		)	6		(25		)	(28		)
Other comprehensive (loss) income	(29		)	6		(25		)	(28		)
Comprehensive Income	5			45		34			79
Less: Pre-acquisition net income of Drop Down Assets	—			8		—			33
Less: Comprehensive income attributable to noncontrolling interests	4			29		35			37
Comprehensive Income (Loss) Attributable to NRG Yield, Inc.	$	1		$	8	$	(1	)	$	9

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

See accompanying notes to consolidated financial statements.

NRG YIELD, INC.

CONSOLIDATED BALANCE SHEETS



	September 30, 2015			December 31, 2014^(a)
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	125		$	406
Restricted cash	69			45
Accounts receivable — trade	104			85
Accounts receivable — affiliate	1			—
Inventory	30			27
Derivative instruments — affiliate	3			—
Notes receivable	7			6
Deferred income taxes	12			16
Prepayments and other current assets	25			21
Total current assets	376			606
Property, plant and equipment
In service	4,929			4,796
Under construction	4			8
Total property, plant and equipment	4,933			4,804
Less accumulated depreciation	(499		)	(338		)
Net property, plant and equipment	4,434			4,466
Other Assets
Equity investments in affiliates	553			227
Notes receivable	11			15
Intangible assets, net of accumulated amortization of $80 and $36	1,377			1,423
Derivative instruments	—			2
Deferred income taxes	124			118
Other non-current assets	114			108
Total other assets	2,179			1,893
Total Assets	$	6,989		$	6,965

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

See accompanying notes to consolidated financial statements.

NRG YIELD, INC.

CONSOLIDATED BALANCE SHEETS (Continued)



	September 30, 2015			December 31, 2014^(a)
LIABILITIES AND STOCKHOLDERS’ EQUITY	(In millions, except share information)
Current Liabilities
Current portion of long-term debt	$	224		$	214
Accounts payable — trade	22			20
Accounts payable — affiliate	58			46
Derivative instruments	42			48
Accrued expenses and other current liabilities	79			61
Total current liabilities	425			389
Other Liabilities
Long-term debt	4,285			4,573
Derivative instruments	74			69
Other non-current liabilities	53			49
Total non-current liabilities	4,412			4,691
Total Liabilities	4,837			5,080
Commitments and Contingencies
Stockholders' Equity
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued	—			—
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 182,848,000 shares issued and outstanding (Class A 34,586,250, Class B 42,738,750, Class C 62,784,250, Class D 42,738,750) and 154,650,000 shares issued and outstanding (Class A 34,586,250, Class B 42,738,750, Class C 34,586,250, Class D 42,738,750) at September 30, 2015 and December 31, 2014, respectively	1			—
Additional paid-in capital	1,820			1,240
Retained earnings	15			3
Accumulated other comprehensive loss	(32		)	(9		)
Noncontrolling interest	348			651
Total Stockholders' Equity	2,152			1,885
Total Liabilities and Stockholders' Equity	$	6,989		$	6,965

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

See accompanying notes to consolidated financial statements.

NRG YIELD, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS



	Nine months ended September 30,
	2015			2014 ^(a)
	(In millions)
Cash Flows from Operating Activities
Net income	$	59		$	107
Adjustments to reconcile net income to net cash provided by operating activities:
Distributions in excess of equity in earnings of unconsolidated affiliates	25			17
Depreciation and amortization	163			112
Amortization of financing costs and debt discount/premiums	11			8
Amortization of intangibles and out-of-market contracts	41			21
Adjustment for debt extinguishment	9			—
Changes in deferred income taxes	8			15
Changes in derivative instruments	(36		)	(14		)
Changes in other working capital	(11		)	(17		)
Net Cash Provided by Operating Activities	269			249
Cash Flows from Investing Activities
Acquisition of businesses, net of cash acquired	(37		)	(901		)
Acquisition of Drop Down Assets, net of cash acquired	(489		)	(336		)
Capital expenditures	(16		)	(28		)
(Increase) decrease in restricted cash	(24		)	20
Decrease in notes receivable	5			6
Proceeds from renewable energy grants	—			137
Net investments in unconsolidated affiliates	(335		)	(17		)
Other	—			11
Net Cash Used in Investing Activities	(896		)	(1,108		)
Cash Flows from Financing Activities
Contributions from noncontrolling interests	119			—
Capital contributions from NRG	—			2
Distributions and return of capital to NRG	—			(45		)
Proceeds from the issuance of common stock	599			630
Payment of dividends and distributions to shareholders	(99		)	(72		)
Proceeds from issuance of long-term debt	589			924
Payment of debt issuance costs	(13		)	(26		)
Payments for long-term debt	(849		)	(220		)
Net Cash Provided by Financing Activities	346			1,193
Net (Decrease) Increase in Cash and Cash Equivalents	(281		)	334
Cash and Cash Equivalents at Beginning of Period	406			59
Cash and Cash Equivalents at End of Period	$	125		$	393

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

See accompanying notes to consolidated financial statements.

NRG YIELD, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1 — Nature of Business

NRG Yield, Inc., together with its consolidated subsidiaries, or the Company, is a dividend growth-oriented company formed as a Delaware corporation on December 20, 2012, to serve as the primary vehicle through which NRG owns, operates and acquires contracted renewable and conventional generation and thermal infrastructure assets. The Company owns 100% of the Class A units and Class C units of NRG Yield LLC, including a controlling interest through its position as managing member. NRG Yield LLC, through its wholly owned subsidiary, NRG Yield Operating LLC, or Yield Operating, is the holder of a portfolio of renewable and conventional generation and thermal infrastructure assets, primarily located in the Northeast, Southwest and California regions of the U.S.

The Company consolidates the results of NRG Yield LLC through its controlling interest, with NRG's interest shown as noncontrolling interest in the financial statements. On May 14, 2015, the Company completed a stock split in connection with which each outstanding share of Class A common stock was split into one share of Class A common stock and one share of Class C common stock, and each outstanding share of Class B common stock was split into one share of Class B common stock and one share of Class D common stock. The stock split is referred to as the Recapitalization and all references to share or per share amounts in the accompanying consolidated financial statements and applicable disclosures have been retrospectively adjusted to reflect the Recapitalization. In addition, on June 29, 2015, NRG Yield, Inc. completed the issuance of 28,198,000 shares of Class C common stock for net proceeds of $599 million. See further discussion in Note 10, Changes in Capital Structure. The holders of the Company's outstanding shares of Class A and Class C common stock are entitled to dividends as declared. NRG receives its distributions from NRG Yield LLC through its ownership of NRG Yield LLC Class B and Class D units.

The following table represents the structure of the Company as of September 30, 2015:

As of September 30, 2015, the Company's operating assets are comprised of the following projects:



Projects	Percentage Ownership		Net Capacity (MW)^(a)	Offtake Counterparty	Expiration
Conventional
GenConn Middletown^(b)	50	%	95	Connecticut Light & Power	2041
GenConn Devon^(b)	50	%	95	Connecticut Light & Power	2040
Marsh Landing	100	%	720	Pacific Gas and Electric	2023
El Segundo	100	%	550	Southern California Edison	2023
Walnut Creek	100	%	485	Southern California Edison	2023
			1,945
Utility Scale Solar
Alpine	100	%	66	Pacific Gas and Electric	2033
Avenal^(b)	50	%	23	Pacific Gas and Electric	2031
Avra Valley	100	%	25	Tucson Electric Power	2032
Blythe	100	%	21	Southern California Edison	2029
Borrego	100	%	26	San Diego Gas and Electric	2038
Roadrunner	100	%	20	El Paso Electric	2031
CVSR	48.95	%	122	Pacific Gas and Electric	2038
Kansas South	100	%	20	Pacific Gas and Electric	2033
TA High Desert	100	%	20	Southern California Edison	2033
Desert Sunlight 250	25	%	63	Southern California Edison	2035
Desert Sunlight 300	25	%	75	Pacific Gas and Electric	2040
			481
Distributed Solar
AZ DG Solar Projects	100	%	5	Various	2025 - 2033
PFMG DG Solar Projects	51	%	4	Various	2032
			9
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^(c)(d)	100	%	137	Southern California Edison	2038^(c)
Alta XI ^(c)(d)	100	%	90	Southern California Edison	2038^(c)
South Trent	100	%	101	AEP Energy Partners	2029
Laredo Ridge	100	%	80	Nebraska Public Power District	2031
Taloga	100	%	130	Oklahoma Gas & Electric	2031
Pinnacle	100	%	55	Maryland Department of General Services and University System of Maryland	2031
Buffalo Bear	100	%	19	Western Farmers Electric Co-operative	2033
Spring Canyon II ^(c)	90.1	%	31	Platte River Power Authority	2038
Spring Canyon III ^(c)	90.1	%	26	Platte River Power Authority	2039
			1,389
Thermal
Thermal equivalent MWt^(e)	100	%	1,310	Various	Various
Thermal generation	100	%	124	Various	Various

Total net capacity (excluding equivalent MWt)^(f)			3,948

(a) Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2015.

(b) On September 30, 2015, the Company acquired NRG's remaining 0.05% for an immaterial amount.

(c) Projects are part of tax equity arrangements, as further described in Note 2, Summary of Significant Accounting Policies.

(d) PPA begins on January 1, 2016.

(e) 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.

(f) Total net capacity excludes capacity for RPV Holdco and DGPV Holdco, which are consolidated by NRG, as further described in Note 5, Variable Interest Entities.

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. Three of the district energy systems are subject to rate regulation by state public utility commissions while the other district energy systems have rates determined by negotiated bilateral contracts.

The Company entered into a management services agreement with NRG for various services, including human resources, accounting, tax, legal, information systems, treasury, and risk management. Costs incurred by the Company under this agreement were $9 million and $7 million for the nine months ended September 30, 2015, and 2014, respectively, which included certain direct expenses incurred by NRG on behalf of the Company.

Stockholders' equity represents the equity associated with the Class A and Class C common stockholders, with the equity associated with the Class B and Class D common stockholder, or NRG, classified as noncontrolling interest.

As described in Note 3, Business Acquisitions, on January 2, 2015, the Company acquired the Laredo Ridge, Tapestry, and Walnut Creek projects, or the January 2015 Drop Down Assets, for total cash consideration of $489 million, including $9 million for working capital, plus assumed debt of $737 million. Additionally, on June 30, 2014, the Company acquired the TA High Desert, Kansas South, and El Segundo projects, or the June 2014 Drop Down Assets, from NRG for total cash consideration of $357 million plus assumed project level debt. These acquisitions were accounted for as transfers 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 since the inception of common control. Accordingly, the Company prepared its consolidated financial statements to reflect the transfers as if they had taken place from the beginning of the financial statements period or from the date the entities were under common control (if later than the beginning of the financial statements period). The January 2015 Drop Down Assets are reflected as if the transfer took place on April 1, 2014, which represents the date these entities were acquired by NRG.

The accompanying unaudited interim consolidated financial statements have been prepared in accordance with the SEC’s regulations for interim financial information. Accordingly, they do not include all of the information and notes required by U.S. 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 annual financial statements for the year ended December 31, 2014. 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 September 30, 2015, and the results of operations, comprehensive income and cash flows for the nine months ended September 30, 2015, and 2014.

Note 2 — Summary of Significant Accounting Policies

Use of Estimates

The preparation of consolidated financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amount of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements. They also impact the reported amount of net earnings during the reporting period. Actual results could be different from these estimates.

Tax Equity Arrangements

Certain portions of the Company’s noncontrolling interests in subsidiaries represent third-party interests in the net assets under certain tax equity arrangements, which are consolidated by the Company, that have been entered into to finance the cost of wind facilities eligible for certain tax credits. Additionally, certain portions of the Company’s investments in unconsolidated affiliates reflect the Company’s interests in tax equity arrangements, that are not consolidated by the Company, that have been entered into to finance the cost of solar energy systems under operating leases eligible for certain tax credits. The Company has determined that the provisions in the contractual agreements of these structures represent substantive profit sharing arrangements. Further, the Company has determined that the appropriate methodology for calculating the noncontrolling interest and investment in unconsolidated affiliates that reflects the substantive profit sharing arrangements is a balance sheet approach utilizing the hypothetical liquidation at book value, or HLBV, method. Under the HLBV method, the amounts reported as noncontrolling interests and investment in unconsolidated affiliates represent the amounts the investors to the tax equity arrangements would hypothetically receive at each balance sheet date under the liquidation provisions of the contractual agreements, assuming the net assets of the funding structures were liquidated at their recorded amounts determined in accordance with U.S. GAAP. The investors’ interests in the results of operations of the funding structures are determined as the difference in noncontrolling interests and

investment in unconsolidated affiliates at the start and end of each reporting period, after taking into account any capital transactions between the structures and the funds’ investors. The calculations utilized to apply the HLBV method include estimated calculations of taxable income or losses for each reporting period.

Noncontrolling Interests

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



	(In millions)
Balance as of December 31, 2014	651
Payment to NRG for acquired January 2015 Drop Down Assets	(489		)
Contributions from noncontrolling interest for Alta Wind X-X1 TE Holdco	119
Noncontrolling interest acquired in Spring Canyon acquisition	74
Comprehensive income	35
Non-cash contributions	10
Cash distributions to NRG	(52		)
Balance as of September 30, 2015	$	348

On June 30, 2015, the Company sold an economic interest in Alta Wind X-XI TE Holdco, holder of the Alta Wind X and Alta Wind XI projects, to a financial institution in order to monetize cash and tax attributes, primarily production tax credits. The net proceeds of $119 million are reflected as noncontrolling interest in the Company's balance sheet.

As described in Note 3, Business Acquisitions, the Company acquired Spring Canyon on May 7, 2015. The Company owns 90.1% of the Class B shares of Spring Canyon. The seller, Invenergy, owns the remaining 9.9% of the Class B shares and the Class A shares are owned by a tax equity investor. The interests of Invenergy and the tax equity investor of $74 million are shown as noncontrolling interests.

On January 2, 2015, the Company acquired the January 2015 Drop Down Assets, as discussed in Note 3, Business Acquisitions. The difference between the cash paid of $489 million and the historical value of the entities' net assets of $61 million, as well as $23 million of AOCL, was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. In addition, as the January 2015 Drop Down Assets were owned by NRG until January 2, 2015, the pre-acquisition earnings of such projects are recorded as attributable to NRG's noncontrolling interest.

Distributions

The following table lists the distributions paid on NRG Yield LLC's Class B and D units during the nine months ended September 30, 2015:



	Third Quarter 2015		Second Quarter 2015		First Quarter 2015
Distributions per Class B	$	0.21	$	0.20	$	0.39
Distributions per Class D	$	0.21	$	0.20	N/A

On November 4, 2015, NRG Yield LLC announced the declaration of a distribution on its units of $0.215 per unit payable on December 15, 2015 to unit holders of record as of December 1, 2015. The portion of the distributions paid by NRG Yield LLC to NRG is recorded as a reduction to the Company's noncontrolling interest balance.

Recent Accounting Developments

ASU 2015-16 — In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments, or ASU No. 2015-16. The amendments of ASU No. 2015-16 require that an acquirer recognize measurement period adjustments to the provisional amounts recognized in a business combination in the reporting period during which the adjustments are determined. Additionally, the amendments of ASU No. 2015-16 require the acquirer to record in the same period's financial statements the effect on earnings of changes in depreciation, amortization or other income effects, if any, as a result of the measurement period adjustment, calculated as if the accounting had been completed at the acquisition date as well as disclosing on either the face of the income statement or in the notes the portion of the amount recorded in current period earnings that would have been recorded in previous reporting periods. The guidance in ASU No. 2015-16 is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. The amendments should be applied prospectively. The adoption of this standard is not expected to have a material impact on the Company's results of operations, cash flows or financial position.

ASU 2015-03 and ASU 2015-15 — In April 2015, the FASB issued ASU No. 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, or ASU No. 2015-03. The amendments of ASU No. 2015-03 were issued to reduce complexity in the balance sheet presentation of debt issuance costs. ASU No. 2015-03 requires that debt issuance costs be presented in the balance sheet as a direct deduction from the carrying amount of debt liability, consistent with debt discounts or premiums. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this standard. Additionally, in August 2015, the FASB issued ASU No. 2015-15, Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements, or ASU No. 2015-15, as ASU No. 2015-03 did not specifically address presentation or subsequent measurement of debt issuance costs related to line-of-credit arrangements. ASU No. 2015-15 allows an entity to continue to defer and present debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The guidance in ASU No. 2015-03 and ASU No. 2015-15 is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption is permitted for financial statements that have not been previously issued. Had the Company adopted this guidance early, other assets would have been lower by $65 million and $67 million with corresponding decreases in debt as of September 30, 2015, and December 31, 2014, respectively. The adoption of this standard will have no impact on the Company's results of operations, cash flows or net assets.

ASU 2015-02 — In February 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis, or ASU No. 2015-02. The amendments of ASU No. 2015-02 were issued in an effort to minimize situations under previously existing guidance in which a reporting entity was required to consolidate another legal entity in which that reporting entity did not have: (1) the ability through contractual rights to act primarily on its own behalf; (2) ownership of the majority of the legal entity's voting rights; or (3) the exposure to a majority of the legal entity's economic benefits. ASU No. 2015-02 affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. The guidance in ASU No. 2015-02 is effective for periods beginning after December 15, 2015. Early adoption is permitted. The Company adopted the standard effective January 1, 2015 and the adoption of this standard did not impact the Company's results of operations, cash flows or financial position.

ASU 2014-16 — In November 2014, the FASB issued ASU No. 2014-16, Derivatives and Hedging (Topic 815): Determining Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or to Equity, or ASU No. 2014-16. The amendments of ASU No. 2014-16 clarify how U.S. GAAP should be applied in determining whether the nature of a host contract is more akin to debt or equity and in evaluating whether the economic characteristics and risks of an embedded feature are "clearly and closely related" to its host contract. The guidance in ASU No. 2014-16 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted. The Company adopted the standard effective January 1, 2015 and the adoption of this standard did not impact the Company's results of operations, cash flows or financial position.

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. The amendments of ASU No. 2014-09 complete the joint effort between the FASB and the International Accounting Standards Board, or IASB, to develop a common revenue standard for U.S. GAAP and International Financial Reporting Standards, or IFRS, and to improve financial reporting. The guidance in ASU No. 2014-09 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 the following steps to be applied by an entity: (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies the performance obligation. In August 2015, the FASB issued ASU 2015-14, which formally deferred the effective date by one year to make the guidance of ASU No. 2014-09 effective for annual reporting periods beginning after December 15, 2017, including interim periods therein. Early adoption is permitted, but not prior to the original effective date, which was for annual reporting periods beginning after December 15, 2016. The Company is currently evaluating the impact of the standard on the Company's results of operations, cash flows and financial position.

Note 3 — Business Acquisitions

2015 Acquisitions

November 2015 Drop Down Assets from NRG

On November 3, 2015, the Company acquired 75% of the Class B interests of NRG Wind TE Holdco, or the November 2015 Drop Down Assets, which owns a portfolio of 12 wind facilities totaling 814 net MW, from NRG for total cash consideration of $210 million, subject to working capital adjustments. The Company will be responsible for its pro-rata share of non-recourse project debt of $193 million and noncontrolling interest associated with a tax equity structure of $165 million (as of September 30, 2015).

The Company funded the acquisition with borrowings from the revolving credit facility. The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid and historical value of the entities' equity was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. Because the transaction constituted a transfer of net assets under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control.

The Class A interests of NRG Wind TE Holdco are owned by a tax equity investor, or Investor, who receives 99% of allocations of taxable income and other items until the flip point, which occurs when the Investor obtains a specified return on its initial investment, at which time the allocations to the Investor change to 8.53%. The Company generally receives 75% of cash available for distribution until the flip point, at which time the allocations to the Company of cash available for distribution change to 68.60%. If the flip point has not occurred by a specified date, 100% of cash available for distribution is allocated to the Investor until the flip point occurs. NRG Wind TE Holdco is a VIE and the Company is the primary beneficiary, through its position as managing member, and consolidates NRG Wind TE Holdco.

The following is a summary of assets and liabilities transferred in connection with the acquisition as of September 30, 2015:



	NRG Wind TE Holdco
	(In millions)
Current assets	$	34
Property, plant and equipment	673
Non-current assets	179
Total assets	886

Debt	193
Other current and non-current liabilities	33
Total liabilities	226
Less: noncontrolling interest	$	289
Net assets acquired	$	371

Supplemental Pro Forma Information

As described above, the Company's acquisition of the November 2015 Drop Down Assets was accounted for as a transfer of entities under common control. The following unaudited supplemental pro forma information represents the results of operations as if the Company had acquired the November 2015 Drop Down Assets on January 1, 2014, including the impact of acquisition accounting with respect to NRG's acquisition of the projects. All net income or losses prior to the Company's acquisition of the projects is reflected as attributable to NRG and, accordingly, no pro forma impact to earnings per Class A and Class C common share was calculated.



	For the three months ended				For the nine months ended
(In millions)	September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014

Operating revenues	$	225	$	200	$	660	$	561
Net income	24		37		42		77

Desert Sunlight — On June 29, 2015, the Company acquired 25% of the membership interest in Desert Sunlight Investment Holdings, LLC, which owns two solar photovoltaic facilities that total 550 MW, located in Desert Center, California from EFS Desert Sun, LLC, an affiliate of GE Energy Financial Services for a purchase price of $285 million. Power generated by the facilities is sold to Southern California Edison and Pacific Gas and Electric under long-term PPAs with approximately 20 years and 25 years of remaining contract life, respectively. The Company accounts for its 25% investment as an equity method investment.

Spring Canyon — On May 7, 2015, the Company acquired a 90.1% interest in Spring Canyon II, a 34 MW wind facility, and Spring Canyon III, a 29 MW wind facility, each located in Logan County, Colorado, from Invenergy Wind Global LLC. The purchase price was funded with cash on hand. Power generated by Spring Canyon II and Spring Canyon III is sold to Platte River Power Authority under long-term PPAs with approximately 24 years of remaining contract life.

University of Bridgeport Fuel Cell — On April 30, 2015, the Company completed the acquisition of the University of Bridgeport Fuel Cell project in Bridgeport, Connecticut from FuelCell Energy, Inc. The project added an additional 1.4 MW of thermal capacity to the Company's portfolio, with a 12 years contract, with the option for a 7-year extension. The acquisition is reflected in the Company's Thermal segment.

January 2015 Drop Down Assets from NRG — On January 2, 2015, the Company acquired the following projects from NRG: (i) Laredo Ridge, an 80 MW wind facility located in Petersburg, Nebraska, (ii) Tapestry, which includes Buffalo Bear, a 19 MW wind facility in Buffalo, Oklahoma; Taloga, a 130 MW wind facility in Putnum, Oklahoma; and Pinnacle, a 55 MW wind facility in Keyser, West Virginia, and (iii) Walnut Creek, a 485 MW natural gas facility located in City of Industry, California, for total cash consideration of $489 million, including $9 million for working capital, plus assumed project-level debt of $737 million. The Company funded the acquisition with cash on hand and drawings under its revolving credit facility. The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid and the historical value of the entities' equity of $61 million, as well as $23 million of AOCL, was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. Since the transaction constituted a transfer of assets under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. NRG acquired the majority of EME's assets, including Laredo Ridge, Tapestry and Walnut Creek, on April 1, 2014.

The following table presents the historical information summary combining the financial information for the January 2015 Drop Down Assets transferred in connection with the acquisition:



	December 31, 2014
	As Previously Reported		Walnut Creek		Tapestry		Laredo Ridge		As Currently Reported
			(In millions)
Current assets	$	539	$	46	$	14	$	7	$	606
Property, plant and equipment	3,487		575		286		118		4,466
Non-current assets	1,726		57		61		49		1,893
Total assets	5,752		678		361		174		6,965


Debt	4,050		437		192		108		4,787
Other current and non-current liabilities	222		62		5		4		293
Total liabilities	4,272		499		197		112		5,080
Net assets	$	1,480	$	179	$	164	$	62	$	1,885

Supplemental Pro Forma Information

As described above, the Company's acquisition of the January 2015 Drop Down Assets was accounted for as a transfer of entities under common control and all periods were retrospectively adjusted to reflect the entities as if they were transferred on the date the entities were under common control, which was April 1, 2014, the date NRG acquired Walnut Creek, Laredo Ridge and Tapestry. The following unaudited supplemental pro forma information represents the results of operations as if the Company had acquired the January 2015 Drop Down Assets on January 1, 2014, including the impact of acquisition accounting with respect to NRG's acquisition of the projects. While the financial statements have been retrospectively adjusted, all net income or losses prior to the Company's acquisition of the projects is reflected as attributable to NRG and accordingly, no pro forma impact to earnings per Class A and Class C common share was calculated.



	For the nine months ended
(In millions)	September 30, 2014

Operating revenues	$	523
Net income	104

Since the acquisition date, the January 2015 Drop Down Assets contributed $106 million in operating revenues and $31 million in net income.

2014 Acquisitions

Alta Wind Portfolio Acquisition — On August 12, 2014, the Company acquired 100% of the membership interests of Alta Wind Asset Management Holdings, LLC, Alta Wind Company, LLC, Alta Wind X Holding Company, LLC and Alta Wind XI Holding Company, LLC, which collectively own seven wind facilities that total 947 MW located in Tehachapi, California and a portfolio of associated land leases, or the Alta Wind Portfolio. Power generated by the Alta Wind Portfolio is sold to Southern California Edison under long-term PPAs, with 21 years of remaining contract life for Alta Wind I-V. The Alta Wind X and XI PPAs begin in 2016 with a term of 22 years and currently sell energy and renewable energy credits on a merchant basis.

The purchase price for the Alta Wind Portfolio was $923 million, which consisted of a base purchase price of $870 million, as well as a payment for working capital of $53 million, plus the assumption of $1.6 billion of non-recourse project-level debt. In order to fund the purchase price, NRG Yield, Inc. completed an equity offering of 12,075,000 shares of its Class A common stock at an offering price of $54.00 per share on July 29, 2014, which resulted in net proceeds of $630 million, after underwriting discounts and expenses. In addition, on August 5, 2014, NRG Yield Operating LLC issued $500 million of Senior Notes, which bear interest at a rate of 5.375% and mature in August 2024.

The acquisition was recorded as a business combination under ASC 805-50, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The accounting for the business combination was completed as of August 11, 2015, at which point the fair values became final. The following table summarizes the provisional amounts recognized for assets acquired and liabilities assumed as of December 31, 2014, as well as adjustments made through August 11, 2015, when the allocation became final.

The purchase price of $923 million was allocated as follows:



	Acquisition Date Fair Value at December 31, 2014		Measurement period adjustments			Revised Acquisition Date
(In millions)
Assets
Cash	$	22	$	—		$	22
Current and non-current assets	49		(2		)	47
Property, plant and equipment	1,304		6			1,310
Intangible assets	1,177		(6		)	1,171
Total assets acquired	2,552		(2		)	2,550

Liabilities
Debt	1,591		—			1,591
Current and non-current liabilities	38		(2		)	36
Total liabilities assumed	1,629		(2		)	1,627
Net assets acquired	$	923	$	—		$	923

Fair value measurements

The fair values of the property, plant and equipment and intangible assets were measured primarily based on significant inputs that are not observable in the market and thus represent a Level 3 measurement as defined in ASC 820. Significant inputs were as follows:

•

Property, plant and equipment — The fair values were determined primarily based on an income method using discounted cash flows and validated using a cost approach based on the replacement cost of the assets less economic obsolescence. The income approach was applied by determining the enterprise value for each acquired entity and subtracting the fair value of the intangible assets and working capital to determine the implied value of the tangible fixed assets. This methodology was primarily relied upon as the forecasted cash flows incorporate the specific attributes of each asset including age, useful life, equipment condition and technology. The income approach also allows for an accurate reflection of current and expected market dynamics such as supply and demand and regulatory environment as of the acquisition date.

•

Intangible Assets - PPAs — The fair values of the PPAs acquired were determined utilizing a variation of the income approach where the incremental future cash flows resulting from the acquired PPAs compared to the cash flows based on current market prices were discounted to present value at a weighted average cost of capital reflective of a market participant. The values were corroborated with available market data. The PPA values will be amortized over the term of the PPAs, which approximate 22 years.

•

Intangible Assets - Leasehold rights — The fair values of the leasehold rights acquired, which represent the contractual right to receive royalty payments equal to a percentage of PPA revenue from certain projects, were determined utilizing the income approach. The values were corroborated with available market data. The leasehold rights values will be amortized over a period of 21 years, which is equal to the average term of the contracts.

June 2014 Drop Down Assets — On June 30, 2014, the Company acquired from NRG: (i) El Segundo, a 550 MW fast-start, gas-fired facility located in Los Angeles County, California; (ii) TA High Desert, a 20 MW solar facility located in Los Angeles County, California; and (iii) Kansas South, a 20 MW solar facility located in Kings County, California. The Company paid total cash consideration of $357 million, which represents a base purchase price of $349 million and $8 million of working capital adjustments. In addition, the acquisition included the assumption of $612 million of project-level debt. 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. The difference between the cash proceeds and the historical value of the net assets was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. Since the transaction constituted a transfer of entities under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. Accordingly, the Company prepared its consolidated financial statements to reflect the transfer as if it had taken place from the beginning of the financial statements period.

Note 4 — Property, Plant and Equipment

The Company’s major classes of property, plant, and equipment were as follows:



	September 30, 2015			December 31, 2014			Depreciable Lives
	(In millions)
Facilities and equipment	$	4,837		$	4,709		2 - 40 Years
Land and improvements	92			87
Construction in progress	4			8
Total property, plant and equipment	4,933			4,804
Accumulated depreciation	(499		)	(338		)
Net property, plant and equipment	$	4,434		$	4,466

Note 5 — Variable Interest Entities, or VIEs

Entity that is Consolidated

Alta TE Holdco — On June 30, 2015, the Company sold an economic interest in Alta TE Holdco to a financial institution in order to monetize certain cash and tax attributes, primarily production tax credits. The financial institution, or Investor, receives 99% of allocations of taxable income and other items until the flip point, which occurs when the Investor obtains a specified return on its initial investment, at which time the allocations to the Investor change to 5%. The Company receives 100% of cash available for distribution in the first year and subsequently receives 94.34% until the flip point, at which time the allocations to the Company of cash available for distribution change to 97.12%, unless the flip point has not occurred by a specified date, which would result in 100% of cash available for distribution allocated to the Investor until the flip point occurs. Alta TE Holdco is a VIE and the Company is the primary beneficiary through its position as managing member, and therefore consolidates Alta TE Holdco. The net proceeds of $119 million are reflected as noncontrolling interest in the Company's balance sheet.

The summarized financial information for Alta TE Holdco consisted of the following:



(In millions)	September 30, 2015
Other current and non-current assets	$	20
Property, plant and equipment	490
Intangible assets	287
Total assets	797
Current and non-current liabilities	13
Total liabilities	13
Noncontrolling interest	124
Net assets less noncontrolling interests	$	660

Entities that are not Consolidated

The Company has interests in entities that are considered VIEs under ASC 810, Consolidation, 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.

NRG DGPV Holdco 1 LLC — On May 8, 2015, NRG Yield DGPV Holding LLC, a subsidiary of the Company and NRG Renew LLC, a subsidiary of NRG, entered into a partnership by forming NRG DGPV Holdco 1 LLC, or DGPV Holdco, the purpose of which is to own or purchase solar power generation projects and other ancillary related assets from NRG Renew LLC, via intermediate funds, including: (i) a tax equity-financed portfolio of 11 recently completed community solar projects representing approximately 11 MW with a weighted average remaining PPA term of 20 years; and (ii) a tax equity-financed portfolio of approximately 29 commercial photovoltaic systems representing approximately 89 MW. The following illustrates the structure of DGPV Holdco:

As of September 30, 2015, the Company's investment in DGPV Holdco related to the recently completed community solar projects was $17 million. Additionally, as of September 30, 2015, the Company's investment related to the commercial photovoltaic systems was $11 million, $9 million of which remained payable at September 30, 2015. DGPV Holdco is considered a VIE under ASC 810, however the Company is not the primary beneficiary and will account for its investment under the equity method. The Company's maximum exposure to loss is limited to its equity investment, which was $28 million as of September 30, 2015.

NRG RPV Holdco 1 LLC — On April 9, 2015, NRG Yield RPV Holding LLC, a subsidiary of the Company and NRG Residential Solar Solutions LLC, a subsidiary of NRG, entered into a partnership by forming NRG RPV Holdco 1 LLC, or RPV Holdco, that will invest in and hold operating portfolios of residential solar assets developed by NRG Home Solar, a subsidiary of NRG, including: (i) an existing, unlevered portfolio of over 2,200 leases across nine states representing approximately 17 MW with a weighted average remaining lease term of approximately 17 years; and (ii) a tax equity-financed portfolios of approximately 13,000 leases representing approximately 90 MW, with an average lease term for the existing and new leases of approximately 17 to 20 years. The following illustrates the structure of RPV Holdco:

The Company invested $26 million in RPV Holdco in April 2015 related to the existing, unlevered portfolio of leases. The Company also invested $21 million of its $150 million commitment in the tax equity-financed portfolios through September 30, 2015. The Company's maximum exposure will be limited to its equity investment. RPV Holdco is considered a VIE under ASC 810, however the Company is not the primary beneficiary, and will account for its investment under the equity method. The Company's maximum exposure to loss is limited to its equity investment, which was $47 million as of September 30, 2015.

GenConn Energy LLC — The Company has a 50% interest in GCE Holding LLC, the owner of GenConn, which owns and operates two 190 MW peaking generation facilities in Connecticut at the Devon and Middletown sites. Each of these facilities was constructed pursuant to a 30-year cost of service type contract with the Connecticut Light & Power Company. GenConn is

considered a VIE under ASC 810, however the Company is not the primary beneficiary, and accounts for its investment under the equity method. Effective September 30, 2015, the Company increased its 49.95% ownership by acquiring an additional 0.05% membership interest from NRG, bringing its total ownership interest to 50%.

The project was funded through equity contributions from the owners and non-recourse, project-level debt. As of September 30, 2015, the Company's investment in GenConn was $110 million and its maximum exposure to loss is limited to its equity investment. Additionally, GenConn has a $237 million project note with an interest rate of 4.73% and a maturity date of July 2041, and a 5-year, $35 million working capital facility that matures in 2018, which can be used to issue letters of credit at an interest rate of 1.875% per annum. As of September 30, 2015, $220 million was outstanding under the note and nothing was drawn on the working capital facility. The note is secured by all of the GenConn assets.

The following table presents summarized financial information for GCE Holding LLC:



	Three months ended September 30,				Nine months ended September 30,
(In millions)	2015		2014		2015		2014
Income Statement Data:
Operating revenues	$	21	$	18	$	61	$	62
Operating income	9		10		29		30
Net income	$	6	$	7	$	20	$	21



	September 30, 2015		December 31, 2014
Balance Sheet Data:	(In millions)
Current assets	$	32	$	33
Non-current assets	420		438
Current liabilities	16		20
Non-current liabilities	$	216	$	223

Desert Sunlight Investment Holdings, LLC - The Company has a 25% membership interest in Desert Sunlight Investment Holdings, LLC, which owns two solar photovoltaic facilities that total 550 MW in Desert Center, California. Power generated by the facilities is sold to Southern California Edison and Pacific Gas and Electric under long-term PPAs with approximately 20 years and 25 years of contract life, respectively. Desert Sunlight is considered a VIE under ASC 810, however the Company is not the primary beneficiary, and accounts for its investment under the equity method.

As of September 30, 2015, the Company's investment in Desert Sunlight was $281 million and its maximum exposure to loss is limited to its equity investment.

The following tables present summarized financial information for Desert Sunlight Investment Holdings, LLC:



	Three months ended September 30,				Nine months ended September 30,
(In millions)	2015		2014		2015		2014
Income Statement Data:
Operating revenues	$	73	$	48	$	170	$	102
Operating income	51		33		108		58
Net income	$	39	$	22	$	70	$	27



	September 30, 2015		December 31, 2014
Balance Sheet Data:	(In millions)
Current assets	$	381	$	706
Non-current assets	1,508		1,519
Current liabilities	91		436
Non-current liabilities	$	1,141	$	1,152

Note 6 — Fair Value of Financial Instruments

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

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



	As of September 30, 2015				As of December 31, 2014
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Assets:
Notes receivable, including current portion	$	18	$	18	$	21	$	21
Liabilities:
Long-term debt, including current portion	$	4,509	$	4,406	$	4,787	$	4,873

The fair value of notes receivable and long-term debt are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments, and are classified as Level 3 within the fair value hierarchy.

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.

Recurring Fair Value Measurements

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



	As of September 30, 2015				As of December 31, 2014
	Fair Value ^(a)		Fair Value ^(a)		Fair Value ^(b)
(In millions)	Level 1		Level 2		Level 2
Derivative assets:
Commodity contracts	$	—	$	3	$	—
Interest rate contracts	—		—		2
Total assets	—		3		2
Derivative liabilities:
Commodity contracts	1		2		3
Interest rate contracts	—		113		114
Total liabilities	$	1	$	115	$	117

^(a) There were no assets or liabilities classified as Level 3 as of September 30, 2015.

^(b) There were no assets or liabilities classified as Level 1 or Level 3 as of December 31, 2014.

Derivative Fair Value Measurements

A portion of the Company's contracts are exchange-traded contracts with readily available quoted market prices. A majority of 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 remainder of the assets and liabilities represent contracts for which external sources or observable market quotes are not available. These contracts are valued using various valuation techniques including, but not limited to, internal models that apply fundamental analysis of the market and corroboration with similar markets. As of September 30, 2015, there were no contracts valued with prices provided by models and other valuation techniques.

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 calculated based on credit default swaps. To the extent that the net exposure is an asset, the Company uses the counterparty’s default swap rate. If the net exposure is a liability, the Company uses its default swap rate. The credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of September 30, 2015, the credit reserve resulted in a $3 million increase in fair value in OCI. 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 as disclosed in Note 2, Summary of Significant Accounting Policies, to the Company's audited consolidated financial statements included in the Company's 2014 Form 10-K, the following item 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 September 30, 2015, credit risk exposure to these counterparties attributable to the Company's ownership interests was approximately $2.9 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 11, Segment Reporting, to the Company's audited consolidated financial statements included in the Company's 2014 Form 10-K. However, such regulated utility counterparties can be impacted by changes in government regulations, which the Company is unable to predict.

Note 7 — 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 audited consolidated financial statements included in the Company's 2014 Form 10-K.

Energy-Related Commodities

As of September 30, 2015, the Company had forward contracts with an NRG subsidiary, hedging the sale of power from the Alta X and Alta XI wind facilities, entered into in the first quarter of 2015 and extending through the end of 2015 and forward contracts for the purchase of fuel commodities relating to the forecasted usage of the Company’s district energy centers extending through 2017. At September 30, 2015, these contracts were not designated as cash flow or fair value hedges.

Interest Rate Swaps

As of September 30, 2015, the Company had interest rate derivative instruments on non-recourse debt extending through 2031, most of which are designated as cash flow hedges.

Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy/(sell) of the Company's open derivative transactions broken out by commodity as of September 30, 2015, and December 31, 2014.



		Total Volume
		September 30, 2015		December 31, 2014
Commodity	Units	(In millions)
Natural Gas	MMBtu	4		2
Interest	Dollars	$	1,786	$	2,817

The decrease in the interest rate position is primarily the result of settling the Alta X and Alta XI interest rate swaps in connection with the repayment of the outstanding project-level debt during the second quarter of 2015, as further described in Note 8, Long-term Debt.

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
	September 30, 2015		December 31, 2014		September 30, 2015		December 31, 2014
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	—	$	—	$	36	$	40
Interest rate contracts long-term	—		2		67		49
Total Derivatives Designated as Cash Flow Hedges	—		2		103		89
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	—		—		3		5
Interest rate contracts long-term	—		—		7		20
Commodity contracts current	3		—		3		3
Total Derivatives Not Designated as Cash Flow Hedges	3		—		13		28
Total Derivatives	$	3	$	2	$	116	$	117

The Company has elected to present derivative assets and liabilities on the balance sheet on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As of September 30, 2015, there was no outstanding collateral paid or received. The following table summarizes the offsetting of derivatives by counterparty master agreement level:



	Gross Amounts Not Offset in the Statement of Financial Position
As of September 30, 2015	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	3		$	(1	)	$	2
Derivative liabilities	(3		)	1			(2		)
Total commodity contracts	—			—			—
Interest rate contracts:
Derivative liabilities	(113		)	—			(113		)
Total interest rate contracts	(113		)	—			(113		)
Total derivative instruments	$	(113	)	$	—		$	(113	)



	Gross Amounts Not Offset in the Statement of Financial Position
As of December 31, 2014	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative liabilities	$	(3	)	$	—		$	(3	)
Total commodity contracts	(3		)	—			(3		)
Interest rate contracts:
Derivative assets	2			(2		)	—
Derivative liabilities	(114		)	2			(112		)
Total interest rate contracts	(112		)	—			(112		)
Total derivative instruments	$	(115	)	$	—		$	(115	)

Accumulated Other Comprehensive Loss

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



	Three months ended September 30,						Nine months ended September 30,
	2015			2014			2015			2014
	(In millions)
Accumulated OCL beginning balance	$	(48	)	$	(34	)	$	(52	)	$	—
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	3			1			10			8
Mark-to-market of cash flow hedge accounting contracts	(32		)	5			(35		)	(36		)
Accumulated OCL ending balance, net of income tax benefit of $19, and $3, respectively	$	(77	)	$	(28	)	$	(77	)	$	(28	)
Accumulated OCL attributable to NRG	(45		)	(22		)	(45		)	(22		)
Accumulated OCL attributable to NRG Yield, Inc.	$	(32	)	$	(6	)	$	(32	)	$	(6	)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4	$	(14	)				$	(14	)

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 or nine months ended September 30, 2015, and 2014.

Impact of Derivative Instruments on the Statements of Operations

The Company has interest rate derivative instruments that are not designated as cash flow hedges. The effect of interest rate hedges is recorded to interest expense. For the three months ended September 30, 2015, and 2014, the impact to the consolidated statements of operations was a loss of $6 million and $0 million, respectively. For the nine months ended September 30, 2015, and 2014, the impact to the consolidated statements of operations was a gain of $13 million and a loss of $6 million, respectively.

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

Commodity contracts also hedge the forecasted sale of power for the Alta X and Alta XI wind facilities until the start of the PPAs on January 1, 2016. The effect of these commodity hedges is recorded to operating revenues. For the three months ended September 30, 2015, the impact to the consolidated statements of operations was an unrealized loss of $1 million. For the nine months ended September 30, 2015, the impact to the consolidated statements of operations was an unrealized gain of $2 million.

See Note 6, Fair Value of Financial Instruments, for discussion regarding concentration of credit risk.

Note 8 — Long-term Debt

This footnote should be read in conjunction with the complete description under Note 9, Long-term Debt, to the Company's 2014 Form 10-K. Long-term debt consisted of the following:



	September 30, 2015		December 31, 2014		September 30, 2015, interest rate % ^(a)
	(In millions, except rates)
Senior Notes, due 2024	$	500	$	500	5.375
Convertible notes, due 2019 ^(b)	329		326		3.50
NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, due 2019 ^(c)	92		—		L+2.75
Convertible notes, due 2020 ^(d)	266		—		3.25
Project-level debt:
Alta Wind I, lease financing arrangement, due 2034	255		261		7.015
Alta Wind II, lease financing arrangement, due 2034	200		205		5.696
Alta Wind III, lease financing arrangement, due 2034	208		212		6.067
Alta Wind IV, lease financing arrangement, due 2034	135		138		5.938
Alta Wind V, lease financing arrangement, due 2035	215		220		6.071
Alta Wind X, due 2021	—		300		L+2.00
Alta Wind XI, due 2021	—		191		L+2.00
Alta Realty Investments, due 2031	33		34		7.00
Alta Wind Asset Management, due 2031	19		20		L+2.375
NRG West Holdings LLC, due 2023 (El Segundo Energy Center)	485		506		L+1.625 - L+2.25
NRG Marsh Landing LLC, due 2017 and 2023	431		464		L+1.75 - L+1.875
Walnut Creek Energy, due 2023	363		391		L+1.625
Tapestry Wind LLC, due 2021	184		192		L+1.625
NRG Solar Alpine LLC, due 2014 and 2022	156		163		L+1.75
NRG Energy Center Minneapolis LLC, due 2017 and 2025	110		121		5.95 -7.25
Laredo Ridge LLC, due 2028	105		108		L+1.875
NRG Solar Borrego LLC, due 2025 and 2038	73		75		L+ 2.50/5.65
South Trent Wind LLC, due 2020	62		65		L+1.625
NRG Solar Avra Valley LLC, due 2031	61		63		L+1.75
TA High Desert LLC, due 2020 and 2032	54		55		L+2.50/5.15
WCEP Holdings LLC, due 2023	46		46		L+3.00
NRG Roadrunner LLC, due 2031	40		42		L+1.625
NRG Solar Kansas South LLC, due 2031	34		35		L+2.00
NRG Solar Blythe LLC, due 2028	22		22		L+1.625
PFMG and related subsidiaries financing agreement, due 2030	30		31		6.00
NRG Energy Center Princeton LLC, due 2017	1		1		5.95
Subtotal project-level debt:	3,322		3,961
Total debt	4,509		4,787
Less current maturities	224		214
Total long-term debt	$	4,285	$	4,573

(a) As of September 30, 2015, L+ equals 3 month LIBOR plus x%, except for the NRG Marsh Landing term loan, Walnut Creek term loan, and the Revolving Credit Facility where L+ equals 1 month LIBOR plus x% and Kansas South where L+ equals 6 month LIBOR plus x%.

(b) Net of discount of $16 million and $19 million as of September 30, 2015, and December 31, 2014, respectively.

(d) Net of discount of $22 million as of September 30, 2015.

The financing arrangements listed above contain certain covenants, including financial covenants that the Company is required to comply with during the term of the respective arrangement. As of September 30, 2015, the Company was in compliance with all of the required covenants.

The discussion below lists changes to or additions of long-term debt for the nine months ended September 30, 2015.

Convertible Notes due 2019

In connection with the Recapitalization, the Company adjusted the conversion rate of its 2019 Convertible Notes. Effective on May 15, 2015, the conversion rate was adjusted to 42.9644 shares of Class A common stock per $1,000 principal amount of 2019 Convertible Notes in accordance with the terms of the related indenture.

NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility

On June 26, 2015, the Company amended the revolving credit facility to, among other things, increase the availability from $450 million to $495 million. As of September 30, 2015, $92 million of borrowings and $25 million of letters of credit were outstanding. On November 3, 2015, the Company borrowed $209 million from the revolving credit facility to finance the acquisition of the November 2015 Drop Down Assets, as discussed in Note 3, Business Acquisitions.

Convertible Senior Notes due 2020

On June 29, 2015, the Company closed on its offering of $287.5 million aggregate principal amount of 3.25% Convertible Senior Notes due 2020, or the 2020 Convertible Notes. The 2020 Convertible Notes are convertible, under certain circumstances, into the Company’s Class C common stock, cash or a combination thereof at an initial conversion price of $27.50 per Class C common share, which is equivalent to an initial conversion rate of approximately 36.3636 shares of Class C common stock per $1,000 principal amount of notes. Interest on the 2020 Convertible Notes is payable semi-annually in arrears on June 1 and December 1 of each year, commencing on December 1, 2015. The 2020 Convertible Notes mature on June 1, 2020, unless earlier repurchased or converted in accordance with their terms. Prior to the close of business on the business day immediately preceding December 1, 2019, the 2020 Convertible Notes will be convertible only upon the occurrence of certain events and during certain periods, and thereafter, at any time until the close of business on the second scheduled trading day immediately preceding the maturity date.

The 2020 Convertible Notes are accounted for in accordance with ASC 470-20. Under ASC 470-20, issuers of convertible debt instruments that may be settled in cash upon conversion, including partial cash settlement, are required to separately account for the liability (debt) and equity (conversion option) components. The application of ACS 470-20 resulted in the recognition of $23 million as the value for the equity component with the offset to debt discount. The debt discount will be amortized to interest expense using the effective interest method over the term of the 2020 Convertible Notes.

Alta Wind X and Alta Wind XI Financing Due 2021

On June 30, 2015, the Company entered into a tax equity financing arrangement through which NRG Yield Operating received $119 million in net proceeds, as described in Note 5, Variable Interest Entities, or VIEs. These proceeds, as well as proceeds obtained from the June 29, 2015, common stock issuance, as described in Note 10, Changes in Capital Structure, and 2020 Convertible Notes issuance, as described above, were utilized to repay all of the outstanding project indebtedness associated with the Alta Wind X and Alta Wind XI wind facilities. The Company also settled interest rate swaps associated with the project level debt for the Alta Wind X and Alta Wind XI wind facilities at a value of $17 million.

Laredo Ridge

On July 27, 2010, Laredo Ridge entered into a credit agreement with a group of lenders for a $75 million construction loan that was convertible to a term loan upon completion of the project, a $53 million cash grant loan and a $3 million working capital loan facility. The project met the conditions to convert to a term loan on March 18, 2011. The cash grant loan was repaid in July 2011 with proceeds of the cash grant. The credit agreement also included a letter of credit facility on behalf of Laredo Ridge of up to $9 million. Laredo Ridge paid a fee equal to the applicable margin on issued letters of credit.

On December 17, 2014, Laredo Ridge amended the credit agreement to increase its term loan borrowings by an additional $41 million to reduce the working capital facility by $1 million, to increase the letter of credit facility by $1 million and to reduce the related interest rate to LIBOR plus 1.875% through December 31, 2018, LIBOR plus 2.125% from January 1, 2019 through December 31, 2023 and LIBOR plus 2.375% from January 1, 2024 through the maturity date. The fee on the working capital facility was reduced to 0.5%. In addition, the maturity date was extended to December 31, 2028. The proceeds were utilized to make a distribution of $33 million to NRG Wind LLC, an NRG subsidiary, with the remaining $8 million utilized to fund the costs of the amendment. As of September 30, 2015, $105 million was outstanding under the term loan, nothing was outstanding under the working capital facility, and $10 million of letters of credit in support of the project were issued.

In connection with the amendment to the credit agreement, Laredo Ridge entered into a series of fixed for floating interest rate swaps that would fix the interest rate for a minimum of 75% of the outstanding notional amount. Laredo Ridge pays its counterparty the equivalent of a 2.31% fixed interest payment on a predetermined notional value, and quarterly, Laredo Ridge will receive the equivalent of a floating interest payment based on the three-month LIBOR calculated on the same notional value through December 31, 2028. All interest rate swap payments by Laredo Ridge and its counterparties are made quarterly and LIBOR is determined in advance of each interest period.

Tapestry Wind LLC

On December 21, 2011, Tapestry Wind LLC entered into a credit agreement with a group of lenders for a $214 million term loan and an $8 million working capital loan facility. The term loan matures in December 2021. It is secured by Tapestry Wind LLC's interest in the Buffalo Bear, Taloga, and Pinnacle projects. The term loan amortizes based upon a predetermined schedule. The working capital facility is available to fund the operating needs of Tapestry Wind LLC. The commitment fee on this facility is 0.75%. The credit agreement also includes a letter of credit facility on behalf of Tapestry Wind LLC of up to $20 million. Tapestry Wind LLC pays a fee equal to the applicable margin on issued letters of credit.

Under the terms of the agreement, Tapestry Wind LLC entered into a series of fixed for floating interest rate swaps that would fix the interest rate for a minimum of 90% of the outstanding notional amount. Tapestry Wind LLC will pay its counterparty the equivalent of a 2.21% fixed interest payment on a predetermined notional value, and quarterly, Tapestry Wind LLC will receive the equivalent of a floating interest payment based on a three-month LIBOR calculated on the same notional value through December 21, 2021. All interest rate swap payments by Tapestry Wind LLC and its counterparties are made quarterly and the LIBOR is determined in advance of each interest period. Swaps became effective December 30, 2011, and amortize in proportion to the term loan. At the same time Tapestry Wind LLC entered into a series of forward starting swaps to hedge the refinancing risk. The swaps are effective December 21, 2021. Tapestry Wind LLC will pay its counterparty the equivalent of a 3.57% fixed interest payment on a predetermined notional value, and quarterly, Tapestry Wind LLC will receive the equivalent of a floating interest payment based on a three-month LIBOR calculated on the same notional value through December 21, 2029.

On November 12, 2014, Tapestry Wind LLC amended the credit agreement to reduce the related interest rate to LIBOR plus 1.625% through December 20, 2018, and LIBOR plus 1.75% from December 21, 2018, through the maturity date. As of September 30, 2015, $184 million was outstanding under the term loan, nothing was outstanding under the working capital facility and $20 million of letters of credit in support of the project were issued.

Walnut Creek

On July 27, 2011, Walnut Creek entered into a credit agreement with a group of lenders for a $442 million construction loan that was convertible to a term loan upon completion of the project, and a $5 million working capital loan facility. The project met the conditions to convert to a term loan on June 21, 2013, and matures in May 2023. The term loan amortizes based upon a predetermined schedule. The working capital facility is available to fund the operating needs of Walnut Creek. The commitment fee on this facility is 0.625%. The Walnut Creek agreement also includes a letter of credit facility on behalf of Walnut Creek of up to $117 million. Walnut Creek pays a fee equal to the applicable margin on issued letters of credit.

Under the terms of the agreement, Walnut Creek entered into a series of fixed for floating interest rate swaps that would fix the interest rate for a minimum of 90% of the outstanding notional amount. Walnut Creek will pay its counterparty the equivalent of a 3.54% fixed interest payment on a predetermined notional value, and quarterly, Walnut Creek will receive the equivalent of a floating interest payment based on a three-month LIBOR calculated on the same notional value through May 31, 2023. All interest rate swap payments by Walnut Creek and its counterparties are made quarterly and the LIBOR is determined in advance of each interest period. Swaps became effective June 28, 2013, and amortize in proportion to the term loan.

On October 21, 2014, Walnut Creek amended the credit agreement to increase its term loan borrowings by an additional $10 million, and to reduce the related interest rate to LIBOR plus 1.625% through September 30, 2018, LIBOR plus 1.75% from October 1, 2018, through September 30, 2022, and LIBOR plus 1.875% from October 1, 2022, through the maturity date. The fee on the working capital facility was reduced to 0.5%. The proceeds were utilized to make a distribution of $6 million to WCEP Holdings LLC with the remaining $4 million utilized to fund the costs of the amendment. In addition, Walnut Creek entered into an additional interest rate swap to maintain the minimum of 90% of the outstanding notional amount being swapped to a fixed interest rate. Walnut Creek pays its counterparty the equivalent of a 4.0025% fixed interest payment on a predetermined notional value, and quarterly, Walnut Creek receives the equivalent of a floating interest payment based on a three-month LIBOR calculated on the same notional value through July 31, 2020. All interest rate swap payments by Walnut Creek and its counterparties are made quarterly and the LIBOR is determined in advance of each interest period. Swaps became effective June 28, 2013, and amortize in proportion to the term loan. As of September 30, 2015, $363 million was outstanding under the term loan, nothing was outstanding under the working capital facility, and $49 million of letters of credit were issued.

WCEP Holdings LLC

On July 27, 2011, WCEP Holdings LLC entered into a credit agreement with a group of lenders for a $53 million construction loan that was convertible to a term loan upon completion of the Walnut Creek project. The Walnut Creek project met the conditions for the WCEP Holdings LLC loan to convert to a term loan on June 21, 2013. The term loan has an interest rate of LIBOR plus an applicable margin of 4%. The term loan matures in May 2023. The term loan amortizes based upon a predetermined schedule.

Under the terms of the credit agreement, WCEP Holdings LLC entered into two fixed for floating interest rate swaps that would fix the interest rate for a minimum of 90% of the outstanding notional amount. WCEP Holdings LLC will pay its counterparty the equivalent of a 4% fixed interest payment on a predetermined notional value, and quarterly, WCEP Holdings LLC will receive the equivalent of a floating interest payment based on a three-month LIBOR calculated on the same notional value through May 31, 2023. All interest rate swap payments by WCEP Holdings LLC and its counterparties are made quarterly and the LIBOR is determined in advance of each interest period. Swaps became effective June 28, 2013, and amortize in proportion to the term loan.

On October 21, 2014, WCEP Holdings LLC amended the credit agreement to reduce the related interest rate to LIBOR plus 3%. The proceeds of the distribution from Walnut Creek were utilized to make an optional repayment of $6 million on the term loan. In addition, WCEP Holdings LLC partially terminated the interest rate agreements so that at least 90% and no more than 100% of the aggregate principal amount of the loans then outstanding will be subject to interest rate agreements. As of September 30, 2015, $46 million was outstanding under the term loan.

Avenal Solar Holdings LLC

On March 18, 2015, Avenal Solar Holdings LLC, one of the Company's equity method investments, amended its credit agreement to increase its borrowings by $43 million and to reduce the related interest rate from 6 month LIBOR plus an applicable margin of 2.25% to 6 month LIBOR plus 1.75% from March 18, 2015, through March 17, 2022, 6 month LIBOR plus 2.00% from March 18, 2022, through March 17, 2027, and 6 month LIBOR plus 2.25% from March 18, 2027, through the maturity date. As a result of the credit agreement amendment, the Company received net proceeds of $20 million after fees from its 49.95% ownership in Avenal. Effective September 30, 2015, the Company increased its ownership to 50% by acquiring an additional 0.05% membership interest in Avenal.

NRG West Holdings LLC

On May 29, 2015, NRG West Holdings LLC amended its financing agreement to increase borrowings under the Tranche A facility by $5 million and to reduce the related interest rate to LIBOR plus an applicable margin of 1.625% from May 29, 2015, to August 31, 2017, LIBOR plus an applicable margin of 1.75% from September 1, 2017, to August 31, 2020, and LIBOR plus 1.875% from September 1, 2020, through the maturity date; to reduce the Tranche B loan interest rate to LIBOR plus an applicable margin of 2.250% from May 29, 2015, to August 31, 2017, LIBOR plus 2.375% from September 1, 2017, to August 31, 2020, and LIBOR plus an applicable margin of 2.50% from September 1, 2020, through the maturity date and to reduce the working capital facility by $9 million. The proceeds of the increased borrowing were used to pay costs associated with the refinancing. Further, the amendment resulted in a $7 million loss on debt extinguishment.

Note 9 — Earnings Per Share

Basic and diluted earnings per common share are computed by dividing net income by the weighted average number of common shares outstanding. Shares issued during the year are weighted for the portion of the year that they were outstanding. The number of shares and per share amounts for the prior periods presented below have been retrospectively restated to reflect the Recapitalization as further described in Note 10, Changes in Capital Structure.

The reconciliation of the Company's basic and diluted earnings per share is shown in the following tables:



	Three months ended September 30,
	2015				2014
(In millions, except per share data)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted earnings per share attributable to NRG Yield, Inc. common stockholders
Net income attributable to NRG Yield, Inc.	$	6	$	11	$	3	$	3
Weighted average number of common shares outstanding	35		63		31		31
Earnings per weighted average common share — basic and diluted ^(a)	$	0.18	$	0.18	$	0.10	$	0.10



	Nine months ended September 30,
	2015				2014
(In millions, except per share data) ^(a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted earnings per share attributable to NRG Yield, Inc. common stockholders
Net income attributable to NRG Yield, Inc.	$	10	$	12	$	8	$	8
Weighted average number of common shares outstanding	35		44		25		25
Earnings per weighted average common share — basic and diluted ^(a)	$	0.28	$	0.28	$	0.31	$	0.31

^(a)Basic and diluted earnings per share might not recalculate due to presenting Net income attributable to NRG Yield, Inc. and Weighted average number of common shares outstanding in millions rather than whole dollars.

With respect to the Class A common stock, there were a total of 15 million and 7 million anti-dilutive outstanding equity instruments for the three months ended September 30, 2015, and 2014, respectively, and 15 million and 6 million anti-dilutive outstanding equity instruments for the nine months ended September 30, 2015, and 2014, respectively, related to the 2019 Convertible Notes. With respect to the Class C common stock, there were a total of 10 million anti-dilutive outstanding equity instruments for the three months ended September 30, 2015, and 4 million anti-dilutive outstanding equity instruments for the nine months ended September 30, 2015, related to the 2020 Convertible Notes.

Note 10 — Changes in Capital Structure

Recapitalization

On May 5, 2015, the Company's stockholders approved amendments to the Company's certificate of incorporation that adjusted the Company’s capital structure by creating two new classes of capital stock, Class C common stock and Class D common stock, and distributed shares of Class C and Class D common stock to holders of the Company's outstanding Class A and Class B common stock, respectively, through a stock split. The Recapitalization became effective on May 14, 2015.

The Class C common stock and Class D common stock have the same rights and privileges and rank equally, share ratably and are identical in all respects to the shares of Class A common stock and Class B common stock, respectively, as to all matters, except that each share of Class C common stock and Class D common stock is entitled to 1/100th of a vote on all stockholder matters. The par value per share of the Company’s Class A common stock and Class B common stock remains unchanged at $0.01 per share after the effect of the stock split described above. Accordingly, the stock split was accounted for as a stock dividend. The Company recorded a transfer between retained earnings and common stock equal to the par value of each share of Class C

common stock and Class D common stock that was issued. The Company also retrospectively adjusted all prior period share and per share amounts in the consolidated financial statements for the effect of the stock dividend, so that all periods are comparable.

Class C Common Stock Issuance

On June 29, 2015, the Company closed on its offering of 28,198,000 shares of Class C common stock at a price of $22 per share, which included 3,678,000 shares of Class C common stock purchased by the underwriters through the exercise of an over-allotment option. Net proceeds to the Company from the sale of the Class C common stock were $599 million, net of underwriting discounts and commissions of $21 million. The Company utilized the proceeds of the offering to acquire 28,198,000 additional Class C units of NRG Yield LLC and, as a result, it currently owns 53.3% of the economic interests of NRG Yield LLC, with NRG retaining 46.7% of the economic interests of NRG Yield LLC.

Dividends to Class A and Class C common stockholders

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the nine months ended September 30, 2015:



	Third Quarter 2015		Second Quarter 2015		First Quarter 2015
Dividends per Class A share	$	0.21	$	0.20	$	0.39
Dividends per Class C share	$	0.21	0.20		N/A

Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations.

On November 4, 2015, the Company announced the declaration of quarterly dividends on its Class A common stock and Class C common stock of $0.215 per share payable on December 15, 2015, to stockholders of record as of December 1, 2015.

The Company also has authorized 10,000,000 shares of preferred stock, par value $0.01 per share. None of the shares of preferred stock have been issued.

Note 11 — 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 cash available for distribution, or CAFD, as well as net income (loss).



	Three months ended September 30, 2015
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	86		$	77		$	46		$	—		$	209
Cost of operations	15			23			31			—			69
Depreciation and amortization	19			26			5			—			50
General and administrative — affiliate	—			—			—			3			3
Acquisition-related transaction and integration costs	—			—			—			1			1
Operating income (loss)	52			28			10			(4		)	86
Equity in earnings of unconsolidated affiliates	3			16			—			—			19
Other income, net	—			1			—			—			1
Loss on debt extinguishment	—			(2		)	—			—			(2		)
Interest expense	(11		)	(32		)	(1		)	(18		)	(62		)
Income (loss) before income taxes	44			11			9			(22		)	42
Income tax expense	—			—			—			8			8
Net Income (Loss)	$	44		$	11		$	9		$	(30	)	$	34
Total Assets	$	2,132		$	4,214		$	434		$	209		$	6,989



	Three months ended September 30, 2014
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	80		$	56		$	48		$	—		$	184
Cost of operations	15			13			32			—			60
Depreciation and amortization	13			16			5			—			34
General and administrative — affiliate	—			—			—			3			3
Acquisition-related transaction and integration costs	—			—			—			2			2
Operating income (loss)	52			27			11			(5		)	85
Equity in earnings of unconsolidated affiliates	4			7			—			—			11
Other income, net	—			—			—			1			1
Interest expense	(14		)	(23		)	(2		)	(9		)	(48		)
Income (loss) before income taxes	42			11			9			(13		)	49
Income tax expense	—			—			—			10			10
Net Income (Loss)	$	42		$	11		$	9		$	(23	)	$	39



	Nine months ended September 30, 2015
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	247		$	224		$	135		$	—		$	606
Cost of operations	51			64			96			—			211
Depreciation and amortization	61			88			14			—			163
General and administrative — affiliate	—			—			—			9			9
Acquisition-related transaction and integration costs	—			—			—			2			2
Operating income (loss)	135			72			25			(11		)	221
Equity in earnings of unconsolidated affiliates	10			19			—			—			29
Other income, net	1			1			—			—			2
Loss on debt extinguishment	(7		)	(2		)	—			—			(9		)
Interest expense	(36		)	(91		)	(5		)	(44		)	(176		)
Income (loss) before income taxes	103			(1		)	20			(55		)	67
Income tax expense	—			—			—			8			8
Net Income (Loss)	$	103		$	(1	)	$	20		$	(63	)	$	59



	Nine months ended September 30, 2014
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	223		$	118		$	156		$	—		$	497
Cost of operations	41			24			108			—			173
Depreciation and amortization	60			38			14			—			112
General and administrative — affiliate	—			—			—			7			7
Acquisition-related transaction and integration costs	—			—			—			2			2
Operating income (loss)	122			56			34			(9		)	203
Equity in earnings of unconsolidated affiliates	11			15			—			—			26
Other income, net	—			1			—			1			2
Interest expense	(40		)	(46		)	(6		)	(17		)	(109		)
Income (loss) before income taxes	93			26			28			(25		)	122
Income tax expense	—			—			—			15			15
Net Income (Loss)	$	93		$	26		$	28		$	(40	)	$	107

Note 12 — Income Taxes

Effective Tax Rate

The income tax provision consisted of the following:



	Three months ended September 30,						Nine months ended September 30,
	2015			2014			2015			2014
	(In millions, except percentages)
Income before income taxes	$	42		$	49		$	67		$	122
Income tax expense	8			10			8			15
Effective income tax rate	19.0		%	20.4		%	11.9		%	12.3		%

For the three and nine months ended September 30, 2015 and 2014, the overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its interest in NRG Yield LLC and production tax credits generated from certain wind facilities.

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

The Company's deferred tax balances reflect cumulative net operating losses and the difference in book and tax basis of the Company's assets primarily due to an increase in the tax basis of property, plant and equipment. The change in tax basis resulted in non-cash additions of $29 million during the nine months ended September 30, 2015, and $65 million during the year ended December 31, 2014, to the Company's additional paid-in capital.

Note 13 — Related Party Transactions

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 September 30, 2015, the base management fee was approximately $7 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 future acquisitions and as a result of a change in the scope of services provided under the Management Services Agreement. During the nine months ended September 30, 2015, the fee was increased by approximately $1 million per year primarily due to the acquisition of the January 2015 Drop Down Assets. Costs incurred under this agreement were $9 million and $7 million for the nine months ended September 30, 2015, and 2014, respectively, 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 $5 million due to NRG in accounts payable — affiliate as of September 30, 2015.

Operation and Maintenance Services (O&M) Agreements by and between Thermal Entities and NRG

On October 1, 2014, NRG entered into Plant O&M Services Agreements with certain wholly-owned subsidiaries of the Company. NRG provides necessary and appropriate services to operate and maintain the subsidiaries' plant operations, businesses and thermal facilities. NRG is to be 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. Prior to October 1, 2014, NRG provided the same services to the Thermal Business on an informal basis. Total fees incurred under the agreements were $21 million for the nine months ended September 30, 2015, and 2014. There was a balance of $30 million and $22 million due to NRG in accounts payable — affiliate as of September 30, 2015, and December 31, 2014, respectively. Subsequent to quarter end, $7 million of the outstanding balance has been paid.

Administrative Services Agreement by and between Marsh Landing and GenOn Energy Services, LLC

Marsh Landing is a party to an administrative services agreement with GenOn Energy Services, LLC, a wholly-owned subsidiary of NRG, which provides invoice processing and payment on behalf of Marsh Landing. Marsh Landing reimburses GenOn Energy Services, LLC for the amounts paid by it. The Company reimbursed costs under this agreement of approximately $11 million for the nine months ended September 30, 2015, and 2014. There was a balance of $1 million and $4 million due to GenOn Energy Services, LLC in accounts payable — affiliate as of September 30, 2015, and December 31, 2014, respectively.

O&M Services Agreements by and between El Segundo and NRG El Segundo Operations

El Segundo incurs fees under an O&M agreement with NRG El Segundo Operations, Inc., a wholly-owned subsidiary of NRG. Under the O&M agreement, NRG El Segundo Operations, Inc. manages, operates and maintains the El Segundo facility for an initial term of ten years following the commercial operations date. For the nine months ended September 30, 2015, and 2014, the costs incurred under the agreement were approximately $4 million and $3 million, respectively. There was a balance of $1 million due to NRG El Segundo in accounts payable — affiliate as of September 30, 2015, and December 31, 2014.

O&M Services Agreements by and between GenConn and NRG

GenConn incurs fees under two O&M agreements with wholly-owned subsidiaries of NRG. The fees incurred under the agreements were $3 million and $5 million for the nine months ended September 30, 2015, and 2014, respectively.

Administrative Services Agreement by and between CVSR and NRG

CVSR is a party to an administrative services agreement with NRG Energy Services LLC, a wholly-owned subsidiary of NRG, which provides O&M services on behalf of CVSR. CVSR reimburses NRG Energy Services LLC for the amounts paid by it. CVSR reimbursed costs under this agreement of $4 million and $5 million for the nine months ended September 30, 2015, and 2014, respectively.

ITEM 2 — Management's Discussion and Analysis of Financial Condition and the Results of Operations

The following discussion analyzes the Company's historical financial condition and results of operations, which were recast to include the effect of the June 2014 Drop Down Assets and January 2015 Drop Down Assets on June 30, 2014, and January 2, 2015, respectively. As further discussed in Note 1, Nature of Business, to the Consolidated Financial Statements, the purchase of these assets was accounted for in accordance with ASC 850-50, Business Combinations - Related Issues, pursuant to which the assets and liabilities transferred to the Company relate to interests under common control by NRG and, accordingly, were recorded at historical cost. The difference between the cash proceeds and historical value of the net assets was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. 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.

As you read this discussion and analysis, refer to the Company's Consolidated Statements of Operations to this Form 10-Q, which present the results of operations for the nine months ended September 30, 2015, and 2014. Also refer to the Company's 2014 Form 10-K, which includes detailed discussions of various items impacting the Company's business, results of operations and financial condition.

The discussion and analysis below has been organized as follows:


•	Executive Summary, including a description of the business and significant events that are important to understanding the results of operations and financial condition;


•	Results of operations, including an explanation of significant differences between the periods in the specific line items of the consolidated statements of operations;


•	Financial condition addressing liquidity position, sources and uses of cash, capital resources and requirements, commitments, and off-balance sheet arrangements;


•	Known trends that may affect the Company’s results of operations and financial condition in the future; and


•	Critical accounting policies which are most important to both the portrayal of the Company's financial condition and results of operations, and which require management's most difficult, subjective or complex judgment.

Executive Summary

Introduction and Overview

The Company is a dividend growth-oriented company formed as a Delaware corporation on December 20, 2012, to serve as the primary vehicle through which NRG owns, operates and acquires contracted renewable and conventional generation and thermal infrastructure assets. The Company believes it is well positioned to be a premier company for investors seeking stable and growing dividend income from a diversified portfolio of lower-risk high-quality assets.

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 3,824 net MW. Each of these assets sells substantially all of its output pursuant to long-term offtake agreements with creditworthy counterparties. The average remaining contract duration of these offtake agreements was approximately 17 years as of September 30, 2015, based on cash available for distribution. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,310 net MWt and electric generation capacity of 124 net MW. These thermal infrastructure assets provide steam, hot water 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.

Significant Event During Quarter

The following significant event has occurred since the filing of the Company's last quarterly report:

November 2015 Drop Down Assets from NRG

On November 3, 2015, the Company acquired 75% of the Class B interests of the November 2015 Drop Down Assets, which own a portfolio of 12 wind facilities totaling 814 net MW, from NRG for total cash consideration of $210 million, subject to working capital adjustments. The Company will be responsible for its pro-rata share of non-recourse project debt of $193 million and noncontrolling interest associated with a tax equity structure of $165 million (as of September 30, 2015).

Regulatory Matters

The Company’s regulatory matters are described in the Company’s 2014 Form 10-K in Item 1, Business — Regulatory Matters.

As owners of power plants and participants in wholesale and thermal energy markets, certain of the Company's subsidiaries are subject to regulation by various federal and state government agencies. These include FERC and the PUCT, as well as other public utility commissions in certain states where the Company's assets are located. Each of the Company's U.S. generating facilities qualifies as an EWG or QF. In addition, the Company is subject to the market rules, procedures and protocols of the various ISO and RTO markets in which it participates. Likewise, the Company must also comply with the mandatory reliability requirements imposed by NERC and the regional reliability entities in the regions where the Company operates.

The Company's operations within the ERCOT footprint are not subject to rate regulation by FERC, as they are deemed to operate solely within the ERCOT market and not in interstate commerce. These operations are subject to regulation by the PUCT.

Environmental Matters

The Company’s environmental matters are described in the Company’s 2014 Form 10-K in Item 1, Business — Environmental Matters and Item 1A, Risk Factors.

The Company is subject to a wide range of environmental laws in the development, construction, ownership and operation of projects. These laws generally require that governmental permits and approvals be obtained before construction and during operation of facilities. The Company is also subject to laws and regulations surrounding the protection of wildlife, including migratory birds, eagles and threatened and endangered species. Environmental laws have become increasingly stringent and the Company expects this trend to continue.

Basis of Presentation

The acquisitions of the June 2014 Drop Down Assets from NRG on June 30, 2014, and the January 2015 Drop Down Assets on January 2, 2015, were accounted for as a transfer of entities under common control. The guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. Accordingly, the Company prepared its consolidated financial statements to reflect the transfers as if they had taken place from the beginning of the financial statements period or from the date the entities were under common control (if later than the beginning of the financial statements period). The January 2015 Drop Down Assets are reflected as if the transfer took place on April 1, 2014, which represents the date these entities were acquired by NRG. Members' equity represents NRG's equity in the subsidiaries, and accordingly, in connection with their acquisition by the Company, the balance was reclassified to noncontrolling interest. The Company reduces net income attributable to its Class A and Class C common stockholders by the pre-acquisition net income for the June 2014 Drop Down Assets and January 2015 Drop Down Assets, collectively, the Drop Down Assets, as it is not available to the stockholders.

Trends Affecting Results of Operations

El Segundo Forced Outage

In January 2015, El Segundo experienced a steam turbine water intrusion resulting in a forced outage on Units 5 and 6. The units returned to service in April 2015. The Company completed a root cause analysis and has implemented steps to prevent a recurrence of the event. The Company reviewed the financial impact of repair costs and lost capacity revenue and expects to collect approximately $4 million of insurance proceeds in the fourth quarter of 2015.

Wind Resource Availability

The Company's results continue to be impacted by lower than normal wind resource availability. While the Company's wind facilities were available, adverse weather had a negative impact on wind resources. The Company cannot predict wind resource availability and its related impact on future results.

Consolidated Results of Operations

The following table provides selected financial information:



	Three months ended September 30,								Nine months ended September 30,
(In millions, except otherwise noted)	2015			2014			Change %		2015			2014			Change %
Operating Revenues
Energy and capacity revenues	$	225		$	203		11		$	645		$	517		25
Contract amortization	(15		)	(19		)	(21	)	(41		)	(20		)	105
Mark-to-market economic hedging activities	(1		)	—			(100	)	2			—			100
Total operating revenues	209			184			14		606			497			22

Operating Costs and Expenses
Cost of fuels	19			20			(5	)	57			73			(22	)
Operations and maintenance	33			27			22		106			73			45
Other costs of operations	17			13			31		48			27			78
Depreciation and amortization	50			34			47		163			112			46
General and administrative — affiliate	3			3			—		9			7			29
Acquisition-related transaction and integration costs	1			2			(50	)	2			2			—
Total operating costs and expenses	123			99			24		385			294			31
Operating Income	86			85			1		221			203			9
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	19			11			73		29			26			12
Other income, net	1			1			—		2			2			—
Loss on debt extinguishment	(2		)	—			100		(9		)	—			100
Interest expense	(62		)	(48		)	29		(176		)	(109		)	61
Total other expense, net	(44		)	(36		)	22		(154		)	(81		)	90
Income Before Income Taxes	42			49			(14	)	67			122			(45	)
Income tax expense	8			10			(20	)	8			15			(47	)
Net Income	34			39			(13	)	59			107			(45	)
Less: Pre-acquisition net income of Drop Down Assets	—			8			(100	)	—			33			(100	)
Net Income Excluding Pre-acquisition Net Income of Drop Down Assets	34			31			10		59			74			(20	)
Less: Net income attributable to noncontrolling interests	17			25			(32	)	37			58			(36	)
Net Income Attributable to NRG Yield, Inc.	$	17		$	6		183		$	22		$	16		38



	Three months ended September 30,		Nine months ended September 30,
Business metrics:	2015	2014	2015	2014
Renewable MWh sold (in thousands) ^(a)	954	680	2,858	1,454
Thermal MWt sold (in thousands)	468	467	1,519	1,576
Thermal MWh sold (in thousands)	92	65	219	189

^(a) Volumes sold do not include the MWh generated by the Company's equity method investments.

Management’s Discussion of the Results of Operations for the Three Months ended September 30, 2015, and 2014

Economic Gross Margin

The Company evaluates its operating performance using the measure of economic gross margin, which is not a GAAP measure and may not be comparable to other companies’ presentations or deemed more useful than the GAAP information provided elsewhere in this report. Economic gross margin is defined as energy and capacity revenue less cost of fuels. Economic gross margin does not include mark-to-market gains or losses on economic hedging activities or contract amortization.

The following tables present the composition of economic gross margin for the three months ended September 30, 2015, and 2014:



	Conventional			Renewables		Thermal			Total
(In millions)
Three months ended September 30, 2015
Energy and capacity revenues	$	88		$	91	$	46		$	225
Cost of fuels	(1		)	—		(18		)	(19		)
Economic gross margin	$	87		$	91	$	28		$	206

Three months ended September 30, 2014
Energy and capacity revenues	$	90		$	64	$	49		$	203
Cost of fuels	—			—		(20		)	(20		)
Economic gross margin	$	90		$	64	$	29		$	183

Economic gross margin increased by $23 million during the three months ended September 30, 2015, compared to the same period in 2014, primarily due to the acquisition of the Alta Wind Portfolio in August 2014.

Operations and Maintenance Expense



	Conventional		Renewables		Thermal		Total
(In millions)
Three months ended September 30, 2015	$	6	$	15	$	12	$	33
Three months ended September 30, 2014	7		9		11		27

Operations and maintenance expense increased by $6 million during the three months ended September 30, 2015, compared to the same period in 2014, primarily due to the Alta Wind Portfolio acquired in August 2014.

Other Costs of Operations

Other costs of operations increased by $4 million during the three months ended September 30, 2015, compared to the same period in 2014, primarily due to an increase in property taxes resulting from the acquisition of the Alta Wind Portfolio in August 2014.

Depreciation and Amortization

Depreciation and amortization increased by $16 million during the three months ended September 30, 2015, compared to the same period in 2014, due to the impact of the adjustments to the acquisition accounting for the January 2015 Drop Down Assets and the acquisition of the Alta Wind Portfolio in August 2014.

Equity in Earnings of Unconsolidated Affiliates

Equity in earnings of unconsolidated affiliates increased by $8 million during the three months ended September 30, 2015, compared to the same period in 2014, due primarily to the acquisition of Desert Sunlight on June 29, 2015, as well as increased equity in earnings from CVSR, partially offset by losses from RPV Holdco.

Interest Expense

Interest expense increased by $14 million during the three months ended September 30, 2015, compared to the same period in 2014, due primarily to:



(In millions)
Increase due to the Senior Notes issued in August 2014 and the 2020 Convertible Notes issued in June 2015	$	7
Increase due to acquisition of the Alta Wind Portfolio in August 2014	5
Increase from changes in the fair value of interest rate swaps	4
Decrease from repricing of project-level financing arrangements and principal repayments	(2		)
	$	14

Income Tax Expense

For the three months ended September 30, 2015, the Company recorded income tax expense of $8 million on pretax income of $42 million. For the same period in 2014, the Company recorded income tax expense of $10 million on pretax income of $49 million. For the three months ended September 30, 2015 and 2014, the Company's overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its interest in NRG Yield LLC and production tax credits generated from certain wind facilities.

Income Attributable to Noncontrolling Interests

For the three months ended September 30, 2015, the Company had income of $22 million attributable to NRG's interest in the Company and a loss of $5 million attributable to non-controlling interests with respect to its tax equity financing arrangements and the application of the HLBV method. For the three months ended September 30, 2014, the Company had income of $25 million attributable to NRG's interest in the Company.

Management’s Discussion of the Results of Operations for the Nine Months ended September 30, 2015, and 2014

Economic gross margin

The following tables present the composition of economic gross margin for the nine months ended September 30, 2015, and 2014:



	Conventional			Renewables		Thermal			Total
(In millions)
Nine months ended September 30, 2015
Energy and capacity revenues	$	251		$	258	$	136		$	645
Cost of fuels	(2		)	—		(55		)	(57		)
Economic gross margin	$	249		$	258	$	81		$	588

Nine months ended September 30, 2014
Energy and capacity revenues	$	233		$	126	$	158		$	517
Cost of fuels	(3		)	—		(70		)	(73		)
Economic gross margin	$	230		$	126	$	88		$	444

Economic gross margin increased by $144 million during the nine months ended September 30, 2015, compared to the same period in 2014 due to:



(In millions)
Increase in Renewables gross margin due to the acquisition of the Alta Wind Portfolio in August 2014 and the Tapestry and Laredo Ridge projects, which were acquired by NRG in April 2014 and sold to the Company on January 2, 2015	$	132
Increase in Conventional gross margin due to Walnut Creek, which was acquired by NRG in April 2014 and sold to the Company on January 2, 2015, partially offset by reduced revenues at El Segundo due to the forced outage in the first half of 2015, returning to service in April 2015	19
Decrease in Thermal gross margin due to milder weather conditions in the first nine months of 2015 compared to 2014	(7		)
	$	144

Contract amortization

Contract amortization increased by $21 million during the nine months ended September 30, 2015, compared to the same period in 2014 due to the amortization of the PPAs acquired in the acquisitions of the Alta Wind Portfolio in August 2014 and the January 2015 Drop Down Assets.

Mark-to-market for economic hedging activities

Mark-to-market results for the nine months ended September 30, 2015, represent the unrealized gains on forward contracts with an NRG subsidiary hedging the sale of power from the Alta X and Alta XI wind facilities extending through the end of 2015, as further described in Note 7 — Accounting for Derivative Instruments and Hedging Activities.

Operations and Maintenance Expense



	Conventional		Renewables		Thermal		Total
(In millions)
Nine months ended September 30, 2015	$	27	$	42	$	37	$	106
Nine months ended September 30, 2014	22		18		33		73

Operations and maintenance expense increased by $33 million during the nine months ended September 30, 2015, compared to the same period in 2014, primarily due to the acquisitions of the Alta Wind Portfolio in August 2014 and the January 2015 Drop Down Assets, as well as El Segundo's forced outage in the first half of 2015, returning to service in April 2015.

Other Costs of Operations

Other costs of operations increased by $21 million during the nine months ended September 30, 2015, compared to the same period in 2014, primarily due an increase in property taxes resulting from the acquisition of the Alta Wind Portfolio in August 2014 and the January 2015 Drop Down Assets.

Depreciation and Amortization

Depreciation and amortization increased by $51 million during the nine months ended September 30, 2015, compared to the same period in 2014, due primarily to the acquisition of the Alta Wind Portfolio in August 2014 and the January 2015 Drop Down Assets.

Equity in Earnings of Unconsolidated Affiliates

Equity in earnings of unconsolidated affiliates increased by $3 million during the nine months ended September 30, 2015, compared to the same period in 2014, due primarily to the acquisition of Desert Sunlight on June 29, 2015, partially offset by losses from RPV Holdco.

Interest Expense

Interest expense increased by $67 million during the nine months ended September 30, 2015, compared to the same period in 2014, due to:



(In millions)
Increase due to the acquisition of the Alta Wind Portfolio in August 2014 and the acquisition of the January 2015 Assets	$	52
Increase due to 2019 Convertible Notes issued in first quarter 2014, Senior Notes due 2024 issued in August 2014, and issuance of the 2020 Convertible Notes in the second quarter 2015	26
Decrease from repricing of project-level financing arrangements and principal repayments	(8		)
Decrease from changes in the fair value of interest rate swaps	(3		)
	$	67

Income Tax Expense

For the nine months ended September 30, 2015, the Company recorded $8 million income tax expense on pretax income of $67 million. For the same period in 2014, the Company recorded income tax expense of $15 million on pretax income of $122 million. For the nine months ended September 30, 2015 and 2014, the overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its interest in NRG Yield LLC and production tax credits generated from certain wind facilities.

Income Attributable to Noncontrolling Interests

For the nine months ended September 30, 2015, the Company had income of $35 million attributable to NRG's interest in the Company and income of $2 million attributable to non-controlling interests with respect to its tax equity financing arrangements and the application of the HLBV method. For the nine months ended September 30, 2014, the Company had income of $58 million attributable to NRG's interest in the Company.

Liquidity and Capital Resources

The Company's principal liquidity requirements are to meet its financial commitments, finance current operations, fund capital expenditures, including acquisitions from time to time, to service debt and to pay dividends. Historically, the Company's predecessor operations were financed as part of NRG's integrated operations and largely relied on internally generated cash flows as well as corporate and/or project-level borrowings to satisfy its capital expenditure requirements. As a normal part of the Company's business, depending on market conditions, the Company will from time to time consider opportunities to repay, redeem, repurchase or refinance its indebtedness. Changes in the Company's operating plans, lower than anticipated sales, increased expenses, acquisitions or other events may cause the Company to seek additional debt or equity financing in future periods. There can be no guarantee that financing will be available on acceptable terms or at all. Debt financing, if available, could impose additional cash payment obligations and additional covenants and operating restrictions.

Liquidity Position

As of September 30, 2015, and December 31, 2014, the Company's liquidity was approximately $572 million and $863 million, respectively, comprised of cash, restricted cash, and availability under the Company's revolving credit facility. The decrease primarily relates to the acquisition of the January 2015 Drop Down Assets. The Company's various financing arrangements are described in Note 8, Long-term Debt.

Management believes that the Company's liquidity position, cash flows from operations and availability under its revolving credit facility will be adequate to meet the Company's financial commitments, debt service obligations, finance growth, operating and maintenance capital expenditures, and to fund dividends to holders of the Company's Class A common stock and Class C common stock, both in the near and longer term. Management continues to regularly monitor the Company's ability to finance the needs of its operating, financing and investing activity within the dictates of prudent balance sheet management.

Credit Ratings

Credit rating agencies rate a firm's public debt securities. These ratings are utilized by the debt markets in evaluating a firm's credit risk. Ratings influence the price paid to issue new debt securities by indicating to the market the Company's ability to pay principal, interest and preferred dividends. Rating agencies evaluate a firm's industry, cash flow, leverage, liquidity, and hedge profile, among other factors, in their credit analysis of a firm's credit risk.

On September 18, 2015, S&P reaffirmed its corporate credit ratings on NRG Yield, Inc. and the Senior Notes due 2024. The rating outlook is stable.

On October 6, 2015, Moody's lowered its corporate credit ratings on NRG Yield, Inc. and the Senior Notes due 2024 to Ba2 from Ba1. The rating outlook is stable.

The following table summarizes the credit ratings for NRG Yield, Inc., and the Senior Notes as of November 4, 2015:



	S&P	Moody's
NRG Yield, Inc.	BB+	Ba2
5.375% Senior Notes, due 2024	BB+	Ba2

Sources of Liquidity

The Company's principal sources of liquidity include cash on hand, cash generated from operations, borrowings under new and existing financing arrangements and the issuance of additional equity and debt securities as appropriate given market conditions. As described in Note 8, Long-term Debt, the Company's financing arrangements consist of the revolving credit facility, the 2019 Convertible Notes, the 2020 Convertible Notes, the Senior Notes and project-level financings for its various assets.

Recapitalization

Effective May 14, 2015, NRG Yield, Inc. amended its certificate of incorporation to create two new classes of capital stock, Class C common stock and Class D common stock, and distributed shares of the Class C common stock and Class D common stock to holders of the NRG Yield, Inc.'s outstanding Class A common stock and Class B common stock, respectively, through a stock split.

In connection with the amendments described above, the ROFO Agreement was amended to make additional assets available to the Company should NRG choose to sell them, including (i) two natural gas facilities totaling 795 MW of net capacity that are expected to reach COD in 2017 and 2020, (ii) an equity interest in a wind portfolio that includes wind facilities totaling approximately 934 MW of net capacity, the majority of which was sold to the Company on November 3, 2015, and (iii) up to $250 million of equity interests in one or more residential or distributed solar generation portfolios developed by affiliates of NRG.

On June 29, 2015, NRG Yield, Inc. issued 28,198,000 shares of Class C common stock for net proceeds, after underwriting discounts and expenses, of $599 million, net of underwriting discounts and commissions of $21 million. The Company utilized the proceeds of the offering to acquire 28,198,000 additional Class C units of NRG Yield LLC and, as a result, it currently owns 53.3% of the economic interests of NRG Yield LLC, with NRG retaining 46.7% of the economic interests of NRG Yield LLC. Additionally, on June 29, 2015, the Company completed an offering of $287.5 million aggregate principal amount of 3.25% Convertible Notes due 2020.

Uses of Liquidity

The Company's requirements for liquidity and capital resources, other than for operating its facilities, are categorized as: (i) debt service obligations, as described more fully in Note 8, Long-term Debt; (ii) capital expenditures; (iii) acquisitions and investments; and (iv) cash dividends to investors.

Capital Expenditures

The Company's capital spending program is mainly focused on maintenance capital expenditures, or costs to maintain the assets currently operating, such as costs to replace or refurbish assets during routine maintenance. The Company develops annual capital spending plans based on projected requirements for maintenance capital. For the nine months ended September 30, 2015, and 2014, the Company used approximately $16 million and $28 million, respectively, to fund capital expenditures. The capital expenditures in the first nine months of 2015 relate to maintenance expenses in the amount of $7 million, as well as growth expenditures for the thermal projects in the amount of $9 million.

Acquisitions and Investments

The Company intends to acquire generation assets developed and constructed by NRG in the future, as well as generation and thermal infrastructure assets from third parties where the Company believes its knowledge of the market, operating expertise and access to capital provides a competitive advantage, and to utilize such acquisitions as a means to grow its cash available for distribution. The following acquisitions and investments have occurred to date in 2015:

•

On November 3, 2015, the Company acquired 75% of the Class B interests of NRG Wind TE Holdco, which owns a portfolio of 12 wind facilities totaling 814 net MW, from NRG for total cash consideration of $210 million, subject to working capital adjustments. The Company will be responsible for its pro-rata share of non-recourse project debt of $193 million and noncontrolling interest associated with a tax equity structure of $165 million (as of September 30, 2015).

•

On June 30, 2015, the Company sold an economic interest in the Alta X and Alta XI wind facilities through a tax equity financing arrangement and received $119 million in net proceeds. These proceeds, as well as proceeds obtained from the Company's equity and debt offerings completed in the second quarter of 2015, as discussed above, were utilized to repay all of the outstanding project indebtedness associated with the Alta X and Alta XI wind facilities.

•

On June 29, 2015, the Company acquired 25% of the membership interest in Desert Sunlight Investment Holdings, LLC, which owns two solar photovoltaic facilities totaling 550 MW, located in Desert Center, California, from EFS Desert Sun, LLC, a subsidiary of GE Energy Financial Services, for a purchase price of $285 million, utilizing a portion of the proceeds from the Class C common stock issuance. The Company's pro-rata share of non-recourse project level debt was $285 million as of September 30, 2015.

•

On May 7, 2015, the Company acquired a 90.1% interest in Spring Canyon II, a 34 MW wind facility, and Spring Canyon III, a 29 MW wind facility, each located in Logan County, Colorado, from Invenergy Wind Global LLC. The purchase price was funded with cash on hand. Power generated by Spring Canyon II and Spring Canyon III is sold to Platte River Power Authority under long-term PPAs with approximately 24 years of remaining contract life.

•

In May 2015, the Company and NRG formed a partnership that will invest in and hold operating portfolios of distributed solar assets developed by NRG Renew, a subsidiary of NRG. The partnership will allow NRG to periodically monetize its distributed solar investments and the Company to invest in a growing segment of the solar market. Under the terms of the partnership agreement, the Company will receive 95% of the economics until achieving a targeted return, expected to be achieved commensurate with the end of the customer contract period, after which NRG will receive 95% of the economics. The Company has initially committed to invest up to $100 million of cash contributions into the partnership over time. The partnership is expected to be fully invested over the next 15 months.


•	On April 30, 2015, the Company completed the acquisition of the University of Bridgeport Fuel Cell project in Bridgeport, Connecticut from FuelCell Energy, Inc. The project added an additional 1.4 MW of thermal capacity with a 12 year contract, with the option for a 7-year extension.

•

On April 9, 2015, NRG and the Company entered into a partnership that will invest in and hold operating portfolios of residential solar assets developed by NRG Home Solar, a subsidiary of NRG, including: (i) an existing, unlevered portfolio of over 2,200 leases across nine states representing approximately 17 MW with a weighted average remaining lease term of approximately 17 years, in which the Company invested $26 million in April 2015; and (ii) tax equity-financed portfolios of approximately 13,000 leases representing approximately 90 MW, with an average lease term for the existing and new leases of approximately 17 to 20 years, in which the Company invested $21 million of its $150 million commitment through September 30, 2015.

•

On January 2, 2015, NRG Yield Operating LLC acquired the following projects from NRG: (i) Laredo Ridge, an 80 MW wind facility located in Nebraska; (ii) the Tapestry projects, which include Buffalo Bear, a 19 MW wind facility in Oklahoma; Taloga, a 130 MW wind facility in Oklahoma; and Pinnacle, a 55 MW wind facility in West Virginia; and (iii) Walnut Creek, a 485 MW natural gas facility located in California, for total cash consideration of $489 million including adjustments of $9 million for working capital, plus assumed project level debt of $737 million. The Company funded the acquisition with cash on hand and approximately $210 million borrowed under the Company's revolving credit facility.

Cash Dividends to Investors

The Company intends to use the amount of cash that it receives from its distributions from NRG Yield LLC to pay quarterly dividends to the holders of its Class A common stock and Class C common stock. NRG Yield LLC intends to distribute to its unit holders in the form of a quarterly distribution all of the cash available for distribution that is generated each quarter, less reserves for the prudent conduct of the business, including among others, maintenance capital expenditures to maintain the operating capacity of the assets. Cash available for distribution is defined as earnings before income taxes, depreciation and amortization, excluding contract amortization, cash interest paid, income taxes paid, maintenance capital expenditures, investments in unconsolidated affiliates, growth capital expenditures, net of capital and debt funding, and principal amortization of indebtedness, and including cash distributions from unconsolidated affiliates. Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.

As a result of the Recapitalization, the Company adjusted its dividend policy to reflect the additional number of shares of Class C common stock outstanding. The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the nine months ended September 30, 2015:



	Third Quarter 2015		Second Quarter 2015		First Quarter 2015
Dividends per Class A share	$	0.21	$	0.20	$	0.39
Dividends per Class C share	$	0.21	$	0.20	N/A

Cash Flow Discussion

The following table reflects the changes in cash flows for the nine months ended September 30, 2015, compared to 2014:



Nine months ended September 30,	2015			2014			Change
	(In millions)
Net cash provided by operating activities	$	269		$	249		$	20
Net cash used in investing activities	(896		)	(1,108		)	212
Net cash provided by financing activities	346			1,193			(847		)

Net Cash Provided By Operating Activities



Changes to net cash provided by operating activities were driven by:	(In millions)
Higher net distributions from unconsolidated affiliates	$	8
Increase in operating income adjusted for non-cash items and changes in working capital	12
	$	20

Net Cash Used In Investing Activities



Changes to net cash used in investing activities were driven by:	(In millions)
Payments to acquire businesses, net of cash acquired (primarily the Alta acquisition in 2014)	$	864
Higher payments made to acquire January 2015 Drop Down Assets on January 2, 2015, compared to the payments made on June 30, 2014, for the June 2014 Drop Down Assets	(153		)
Decrease in capital expenditures due to several projects being placed in service in early 2014	12
Changes in restricted cash primarily due to cash transfers in connection with higher debt principal payments in 2015	(44		)
Proceeds from renewable grants in 2014	(137		)
Increase in net investments in unconsolidated affiliates in 2015, compared to 2014, primarily due to the investment in Desert Sunlight made on June 29, 2015	(318		)
Other	(12		)
	$	212

Net Cash Provided By Financing Activities



Changes in net cash provided by financing activities were driven by:	(In millions)
Contributions from non-controlling interests in 2015	$	119
Payment of dividends and returns of capital to NRG, partially offset by contributions from NRG in the first nine months of 2014	43
Increase in dividends and distributions paid	(27		)
Lower net proceeds from Class C equity offering on June 29, 2015, compared to the net proceeds from Class A equity offering on July 29, 2014	(31		)
Increase in debt payments, as well as decrease in proceeds from long-term debt in the first nine months of 2015, compared to 2014	(964		)
Decrease in debt issuance costs due to lower borrowings in the first nine months of 2015	13
	$	(847	)

NOLs, Deferred Tax Assets and Uncertain Tax Position Implications, under ASC 740

As of September 30, 2015, the Company has a cumulative federal NOL carry forward balance of $269 million for financial statement purposes, which will begin expiring in 2033. As a result of the Company's tax position, and based on current forecasts, the Company does not anticipate significant income tax payments for federal, state and local jurisdictions in 2015.

The Company is subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state jurisdictions. The Company is not subject to U.S. federal or state income tax examinations for years prior to 2013.

As of September 30, 2015, the Company has net deferred tax assets of $136 million, which the Company believes are realizable primarily through the generation of future income before income taxes. In order to be able to consider future earnings in the assessment of the realizability of deferred tax assets, generally accepted accounting principles indicate the Company should not have cumulative losses in the recent past. Should the Company determine it cannot utilize estimates of future earnings in its assessment, it could be required to establish a valuation allowance for up to the full amount of its deferred tax asset.

The Company has no uncertain tax benefits.

Off-Balance Sheet Arrangements

Obligations under Certain Guarantee Contracts

The Company may enter into guarantee arrangements in the normal course of business to facilitate commercial transactions with third parties.

Retained or Contingent Interests

The Company does not have any material retained or contingent interests in assets transferred to an unconsolidated entity.

Obligations Arising Out of a Variable Interest in an Unconsolidated Entity

Variable interest in equity investments — As of September 30, 2015, the Company has several investments with an ownership interest percentage of 50% or less in energy and energy-related entities that are accounted for under the equity method. GenConn Energy LLC and Desert Sunlight Investment Holdings LLC are both variable interest entities for which the Company is not the primary beneficiary.

The Company's pro-rata share of non-recourse debt held by unconsolidated affiliates was approximately $857 million as of September 30, 2015. This indebtedness may restrict the ability of these subsidiaries to issue dividends or distributions to the Company. See also Note 5, Variable Interest Entities, or VIEs.

Contractual Obligations and Commercial Commitments

The Company has a variety of contractual obligations and other commercial commitments that represent prospective cash requirements in addition to our capital expenditure programs, as disclosed in the Company's 2014 Form 10-K. See also Note 8, Long-term Debt, for additional discussion of contractual obligations incurred during the nine months ended September 30, 2015.

Fair Value of Derivative Instruments

The Company may enter into fuel purchase contracts and other energy-related financial instruments to mitigate variability in earnings due to fluctuations in spot market prices and to hedge fuel requirements at certain generation facilities. In addition, in order to mitigate interest rate risk associated with the issuance of variable rate debt, the Company enters into interest rate swap agreements.

The tables below disclose the activities that include both exchange and non-exchange traded contracts accounted for at fair value in accordance with ASC 820. Specifically, these tables disaggregate realized and unrealized changes in fair value; disaggregate estimated fair values at September 30, 2015, based on their level within the fair value hierarchy defined in ASC 820; and indicate the maturities of contracts at September 30, 2015. For a full discussion of the Company's valuation methodology of its contracts, see Derivative Fair Value Measurements in Note 6, Fair Value of Financial Instruments.



Derivative Activity Gains/(Losses)	(In millions)
Fair value of contracts as of December 31, 2014	$	(115	)
Contracts realized or otherwise settled during the period	50
Changes in fair value	(48		)
Fair Value of Contracts as of September 30, 2015	$	(113	)



	Fair Value of Contracts as of September 30, 2015
	Maturity
Fair value hierarchy Gains/(Losses)	1 Year or Less			Greater Than 1 Year to 3 Years			Greater Than 3 Years to 5 Years			Greater Than 5 Years			Total Fair Value
	(In millions)
Level 1	$	(1	)	$	—		$	—		$	—		$	(1	)
Level 2	$	(38	)	$	(48	)	$	(19	)	$	(7	)	$	(112	)
Total	$	(39	)	$	(48	)	$	(19	)	$	(7	)	$	(113	)

The Company has elected to disclose derivative assets and liabilities on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As discussed below in Quantitative and Qualitative Disclosures about Market Risk -Commodity Price Risk, NRG, on behalf of the Company, measures the sensitivity of the portfolio to potential changes in market prices using VaR, a statistical model which attempts to predict risk of loss based on market price and volatility. NRG's risk management policy places a limit on one-day holding period VaR, which limits the net open position.

Critical Accounting Policies and Estimates

The Company's discussion and analysis of the financial condition and results of operations are based upon the consolidated financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of these financial statements and related disclosures in compliance with U.S. GAAP requires the application of appropriate technical accounting rules and guidance as well as the use of estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities. The application of these policies necessarily involves judgments regarding future events, including the likelihood of success of particular projects, legal and regulatory challenges, and the fair value of certain assets and liabilities. These judgments, in and of themselves, could materially affect the financial statements and disclosures based on varying assumptions, which may be appropriate to use. In addition, the financial and operating environment may also have a significant effect, not only on the operation of the business, but on the results reported through the application of accounting measures used in preparing the financial statements and related disclosures, even if the nature of the accounting policies has not changed.

On an ongoing basis, the Company evaluates these estimates, utilizing historic experience, consultation with experts and other methods the Company considers reasonable. In any event, actual results may differ substantially from the Company's estimates. Any effects on the Company's business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the information that gives rise to the revision becomes known.

The Company's significant accounting policies are summarized in Note 2, Summary of Significant Accounting Policies. The Company identifies its most critical accounting policies as those that are the most pervasive and important to the portrayal of the Company's financial position and results of operations, and that require the most difficult, subjective and/or complex judgments by management regarding estimates about matters that are inherently uncertain. The Company's critical accounting policies include income taxes and valuation allowance for deferred tax assets, impairment of long lived assets and other intangible assets and acquisition accounting.

Recent Accounting Developments

See Note 2, Summary of Significant Accounting Policies, for a discussion of recent accounting developments.

ITEM 3 — Quantitative and Qualitative Disclosures About Market Risk

The Company is exposed to several market risks in its normal business activities. Market risk is the potential loss that may result from market changes associated with the Company's power generation or with an existing or forecasted financial or commodity transaction. The types of market risks the Company is exposed to are commodity price risk, interest rate risk, liquidity risk, and credit risk.

Commodity Price Risk

Commodity price risks result from exposures to changes in spot prices, forward prices, volatilities, and correlations between various commodities, such as electricity, natural gas and emissions credits. The Company manages the commodity price risk of its merchant generation operations by entering into derivative or non-derivative instruments to hedge the variability in future cash flows from forecasted power sales or purchases of fuel. The portion of forecasted transactions hedged may vary based upon management's assessment of market, weather, operation and other factors.

Based on a sensitivity analysis using simplified assumptions, the impact of a $0.50 per MMBtu increase or decrease in natural gas prices across the term of the derivative contracts would cause no change to the net value of derivatives as of September 30, 2015.

Interest Rate Risk

The Company is exposed to fluctuations in interest rates through its issuance of variable rate debt. Exposures to interest rate fluctuations may be mitigated by entering into derivative instruments known as interest rate swaps, caps, collars and put or call options. These contracts reduce exposure to interest rate volatility and result in primarily fixed rate debt obligations when taking into account the combination of the variable rate debt and the interest rate derivative instrument. NRG's risk management policies allow the Company to reduce interest rate exposure from variable rate debt obligations.

Most of the Company's project subsidiaries enter into interest rate swaps, intended to hedge the risks associated with interest rates on non-recourse project level debt. See Note 9, Long-Term Debt, to the Company's audited consolidated financial statements included in the Company's 2014 Form 10-K, and Note 8, Long-term Debt, to this Form 10-Q for more information about interest rate swaps of the Company's project subsidiaries.

If all of the above swaps had been discontinued on September 30, 2015, the Company would have owed the counterparties $116 million. Based on the investment grade rating of the counterparties, the Company believes its exposure to credit risk due to nonperformance by counterparties to its hedge contracts to be insignificant.

The Company has long-term debt instruments that subject it to the risk of loss associated with movements in market interest rates. As of September 30, 2015, a 1% change in interest rates would result in an approximately $3 million change in market interest expense on a rolling twelve month basis.

As of September 30, 2015, the fair value of the Company's debt was $4,406 million and the carrying value was $4,509 million. The Company estimates that a 1% decrease in market interest rates would have increased the fair value of its long-term debt by $372 million.

Liquidity Risk

Liquidity risk arises from the general funding needs of the Company's activities and in the management of the Company's assets and liabilities.

Counterparty Credit Risk

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; and (ii) the use of credit mitigation measures such as prepayment arrangements or volumetric limits. 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.

ITEM 4 — Controls and Procedures

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures

Under the supervision and with the participation of the Company's management, including its principal executive officer, principal financial officer and principal accounting officer, the Company conducted an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures, as such term is defined in Rules 13a-15(e) or 15d-15(e) of the Exchange Act. Based on this evaluation, the Company's principal executive officer, principal financial officer and principal accounting officer concluded that the disclosure controls and procedures were effective as of the end of the period covered by this Quarterly Report on Form 10-Q.

Changes in Internal Control over Financial Reporting

There were no changes in the Company’s internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred in the third quarter of 2015 that materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II - OTHER INFORMATION

ITEM 1 — LEGAL PROCEEDINGS

None.

ITEM 1A — RISK FACTORS

Information regarding risk factors appears in Part I, Item 1A, Risk Factors in the Company's 2014 Form 10-K. There have been no material changes in the Company's risk factors since those reported in its 2014 Form 10-K.

ITEM 2 — UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3 — DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4 — MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5 — OTHER INFORMATION

None.

ITEM 6 — EXHIBITS



Number	Description	Method of Filing
2.1	Purchase and Sale Agreement, dated as of September 17, 2015, by and between NRG Energy Gas & Wind Holdings, Inc. and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.1 to the Company's Current Report on Form 8-K filed on September 21, 2015.
31.1	Rule 13a-14(a)/15d-14(a) certification of David Crane.	Filed herewith.
31.2	Rule 13a-14(a)/15d-14(a) certification of Kirkland B. Andrews.	Filed herewith.
31.3	Rule 13a-14(a)/15d-14(a) certification of David Callen.	Filed herewith.
32	Section 1350 Certification.	Filed herewith.
101 INS	XBRL Instance Document.	Filed herewith.
101 SCH	XBRL Taxonomy Extension Schema.	Filed herewith.
101 CAL	XBRL Taxonomy Extension Calculation Linkbase.	Filed herewith.
101 DEF	XBRL Taxonomy Extension Definition Linkbase.	Filed herewith.
101 LAB	XBRL Taxonomy Extension Label Linkbase.	Filed herewith.
101 PRE	XBRL Taxonomy Extension Presentation Linkbase.	Filed herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	NRG YIELD, INC. (Registrant)

	/s/ DAVID CRANE
	David Crane
	Chief Executive Officer (Principal Executive Officer)


	/s/ KIRKLAND B. ANDREWS
	Kirkland B. Andrews
	Chief Financial Officer (Principal Financial Officer)


	/s/ DAVID CALLEN
	David Callen
Date: November 4, 2015	Chief Accounting Officer (Principal Accounting Officer)