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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K



x		ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Fiscal Year ended December 31, 2017.

o		TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Transition period from to .

Commission File Number: 333-203369

NRG Yield LLC

(Exact name of registrant as specified in its charter)



Delaware (State or other jurisdiction of incorporation or organization)		32-0407370 (I.R.S. Employer Identification No.)

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

(609) 524-4500

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

None

Securities registered pursuant to Section 12(g) of the Act:

None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o No x

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act. Yes x No o

Indicate by check mark whether the registrant (1) has filed all reports 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. (Note: The registrant is a voluntary filer and not subject to the filing requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934. Although not subject to these filing requirements, the registrant has filed all reports that would have been required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months had the registrant been subject to such requirements.) Yes o 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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of the registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. x

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



Large accelerated filer o	Accelerated filer o	Non-accelerated filer x	Smaller reporting company o	Emerging Growth Company o
		(Do not check if a smaller reporting company)

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes o No x

NRG Yield LLC's outstanding equity interests are held by NRG Yield, Inc. and NRG Energy, Inc. and there are no equity interests held by non-affiliates.

Indicate the number of shares outstanding of each of the registrant's classes of common stock as of the latest practicable date. There is no public market for the registrant's outstanding units.



Class		Outstanding at January 31, 2018
Class A Units		34,586,250
Class B Units		42,738,750
Class C Units		64,730,519
Class D Units		42,738,750

Documents Incorporated by Reference:

None.

NOTE: WHEREAS NRG YIELD LLC MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION I(1)(a) AND (b) OF FORM 10-K, THIS FORM 10-K IS BEING FILED WITH THE REDUCED DISCLOSURE FORMAT PURSUANT TO GENERAL INSTRUCTION I(2).

TABLE OF CONTENTS

Index



GLOSSARY OF TERMS	3
PART I	7
Item 1 — Business	7
Item 1A — Risk Factors	13
Item 1B — Unresolved Staff Comments	29
Item 2 — Properties	30
Item 3 — Legal Proceedings	33
Item 4 — Mine Safety Disclosures	33
PART II	34
Item 5 — Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	34
Item 6 — Selected Financial Data	35
Item 7 — Management's Discussion and Analysis of Financial Condition and Results of Operations	36
Item 7A — Quantitative and Qualitative Disclosures About Market Risk	59
Item 8 — Financial Statements and Supplementary Data	59
Item 9 — Changes in Disagreements With Accountants on Accounting and Financial Disclosure	60
Item 9A — Controls and Procedures	60
Item 9B — Other Information	60
PART III	61
Item 10 — Directors, Executive Officers and Corporate Governance	61
Item 11 — Executive Compensation	61
Item 12 — Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	61
Item 13 — Certain Relationships and Related Transactions, and Director Independence	61
Item 14 — Principal Accounting Fees and Services	61
PART IV	63
Item 15 — Exhibits, Financial Statement Schedules	63
EXHIBIT INDEX	119
Item 16 — Form 10-K Summary	124

GLOSSARY OF TERMS

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



2019 Convertible Notes		Yield, Inc.'s $345 million aggregate principal amount of 3.50% Convertible Notes due 2019
2020 Convertible Notes		Yield, Inc.'s $287.5 million aggregate principal amount of 3.25% Convertible Notes due 2020
2024 Senior Notes		$500 million aggregate principal amount of 5.375% unsecured senior notes due 2024, issued by NRG Yield Operating LLC
2026 Senior Notes		$350 million aggregate principal amount of 5.00% unsecured senior notes due 2026, issued by NRG Yield Operating LLC
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
ARO		Asset Retirement Obligation
ARRA		American Recovery and Reinvestment Act of 2009
ASC		The FASB Accounting Standards Codification, which the FASB established as the source of authoritative GAAP
ASU		Accounting Standards Updates – updates to the ASC
ATM Program		At-The-Market Equity Offering Program
August 2017 Drop Down Assets		The remaining 25% interest in NRG Wind TE Holdco, an 814 net MW portfolio of twelve wind projects, acquired from NRG on August 1, 2017
Buckthorn Solar		The 154 MW Buckthorn Solar project
Buffalo Bear		Buffalo Bear, LLC, the operating subsidiary of Tapestry Wind LLC, which owns the Buffalo Bear project
CAA		Clean Air Act
CAFD		Cash Available For Distribution, which the Company defines as net income before interest expense, income taxes, depreciation and amortization, plus cash distributions from unconsolidated affiliates, cash receipts from notes receivable, less cash distributions to noncontrolling interests, maintenance capital expenditures, pro-rata EBITDA from unconsolidated affiliates, cash interest paid, income taxes paid, principal amortization of indebtedness and changes in prepaid and accrued capacity payments
Carlsbad		The Carlsbad Energy Center, a 527 MW natural gas fired project located in Carlsbad, CA
CfD		Contract for Differences
CFTC		U.S. Commodity Future Trading Commission
COD		Commercial Operation Date
Code		Internal Revenue Code of 1986, as amended
Company		NRG Yield LLC, together with its consolidated subsidiaries
CVSR		California Valley Solar Ranch
CVSR Drop Down		The Company's acquisition from NRG of the remaining 51.05% interest of CVSR Holdco
CVSR Holdco		CVSR Holdco LLC, the indirect owner of CVSR
DGPV Holdco 1		NRG DGPV Holdco 1 LLC
DGPV Holdco 2		NRG DGPV Holdco 2 LLC
DGPV Holdco 3		NRG DGPV Holdco 3 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, January 2015 Drop Down Assets, November 2015 Drop Down Assets, CVSR Drop Down, March 2017 Drop Down Assets, August 2017 Drop Down Assets and November 2017 Drop Down Assets
Economic Gross Margin		Energy and capacity revenue, less cost of fuels
EDA		Equity Distribution Agreement
EGU		Electric Utility Generating Unit



El Segundo		NRG West Holdings LLC, the subsidiary of Natural Gas Repowering LLC, which owns the El Segundo Energy Center project
EPC		Engineering, Procurement and Construction
ERCOT		Electric Reliability Council of Texas, the ISO 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
FPA		Federal Power Act
GAAP		Accounting principles generally accepted in the U.S.
GenConn		GenConn Energy LLC
GHG		Greenhouse gas
GIP		Global Infrastructure Partners
GW		Gigawatt
HLBV		Hypothetical Liquidation at Book Value
IASB		International Accounting Standards Board
IRS		Internal Revenue Service
ISO		Independent System Operator, also referred to as Regional Transmission Organization, or RTO
ITC		Investment Tax Credit
January 2015 Drop Down Assets		The Laredo Ridge, Tapestry and Walnut Creek projects, which were acquired by Yield Operating LLC 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 Yield Operating LLC 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
KPPH		1,000 Pounds Per Hour
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
Management Services Agreement		Agreement between NRG and the Company for various operational, management and administrative services
March 2017 Drop Down Assets		(i) Agua Caliente Borrower 2 LLC, which owns a 16% interest (approximately 31% of NRG's 51% interest) in the Agua Caliente solar farm and (ii) NRG's 100% ownership in the Class A equity interests in the Utah Solar Portfolio (defined below), both acquired by the Company on March 27, 2017
Marsh Landing		NRG Marsh Landing LLC, formerly GenOn Marsh Landing LLC
May 9, 2017 Form 8-K		NRG Yield, Inc.'s Current Report on Form 8-K filed with the SEC on May 9, 2017 in connection with NRG Yield Operating LLC's acquisition of the March 2017 Drop Down Assets
MMBtu		Million British Thermal Units
MW		Megawatt
MWh		Saleable megawatt hours, net of internal/parasitic load megawatt-hours
MWt		Megawatts Thermal Equivalent
NECP		NRG Energy Center Pittsburgh LLC
NERC		North American Electric Reliability Corporation
Net Exposure		Counterparty credit exposure to NRG Yield, Inc. net of collateral
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, which was acquired by Yield Operating LLC from NRG on November 3, 2015



November 2017 Drop Down Assets		38 MW portfolio of distributed and small utility-scale solar assets, primarily comprised of assets from NRG's Solar Power Partners (SPP) funds, in addition to other projects developed since the acquisition of SPP by NRG, which was acquired by NRG Yield Operating LLC from NRG on November 1, 2017
NO_x		Nitrogen Oxides
NPNS		Normal Purchases and Normal Sales
NRG		NRG Energy, Inc.
NRG Power Marketing		NRG Power Marketing LLC
NRG ROFO Agreement		Second Amended and Restated Right of First Offer Agreement between the Company and NRG
NRG Transaction		On February 6, 2018, GIP entered into a purchase and sale agreement with NRG for the acquisition of NRG's full ownership interest in Yield, Inc., and NRG's renewable energy development and operations platform. GIP, NRG and the Company also entered into a consent and indemnity agreement in connection with the purchase and sale agreement.
NRG Transformation Plan		A three-year, three-part improvement plan announced by NRG on July 12, 2017, which includes exploring strategic alternatives for NRG's renewables platform and its interest in the Company
NRG Wind TE Holdco		NRG Wind TE Holdco LLC
OCI/OCL		Other comprehensive income/loss
O&M		Operations and Maintenance
OSHA		Occupational Safety and Health Administration
PG&E		Pacific Gas & Electric Company
Pinnacle		Pinnacle Wind, LLC, the operating subsidiary of Tapestry Wind LLC, which owns the Pinnacle project
PJM		PJM Interconnection, LLC
PPA		Power Purchase Agreement
PTC		Production Tax Credit
PUCT		Public Utility Commission of Texas
PUHCA		Public Utility Holding Company Act of 2005
PURPA		Public Utility Regulatory Policies Act of 1978
QF		Qualifying Facility under PURPA
REC		Renewable Energy Certificate
Recapitalization		The adoption of the Company's Second Amended and Restated Certificate of Incorporation which authorized two new classes of common stock, Class C common stock and Class D common stock, and distributed shares of such new classes of common stock to holders of the Company’s outstanding Class A common stock and Class B common stock, respectively, through a stock split on May 14, 2015
ROFO Assets		Specified assets subject to sale, as described in the NRG ROFO Agreement
RPM		Reliability Pricing Model
RPS		Renewable Portfolio Standards
RPV Holdco		NRG RPV Holdco 1 LLC
RTO		Regional Transmission Organization
SCE		Southern California Edison
SEC		U.S. Securities and Exchange Commission
Senior Notes		Collectively, the 2024 Senior Notes and the 2026 Senior Notes
SO₂		Sulfur Dioxide
SPP		Solar Power Partners
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



Tax Act		Tax Cuts and Jobs Act of 2017
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
UPMC		University of Pittsburgh Medical Center
U.S.		United States of America
U.S. DOE		U.S. Department of Energy
Utah Solar Portfolio		Collection consists of Four Brothers Solar, LLC, Granite Mountain Holdings, LLC, and Iron Springs Holdings, LLC, which are equity investments owned by Four Brothers Holdings, LLC, Granite Mountain Renewables, LLC, and Iron Springs Renewables, LLC, respectively, and are part of the March 2017 Drop Down Assets acquisition that closed on March 27, 2017
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
Yield, Inc.		NRG Yield, Inc.
Yield Operating LLC		NRG Yield Operating LLC, the holding company that owns the project companies and is a wholly owned subsidiary of NRG Yield LLC

PART I

Item 1 — Business

General

NRG Yield LLC, together with its consolidated subsidiaries, or the Company, was formed as a Delaware limited liability company on March 5, 2013 to serve as the primary vehicle through which NRG owns, operates and acquires contracted renewable and conventional generation and thermal infrastructure assets. On February 6, 2018, Global Infrastructure Partners, or GIP, entered into a purchase and sale agreement with NRG, or the NRG Transaction, for the acquisition of NRG’s full ownership interest in NRG Yield, Inc. and NRG’s renewable energy development and operations platform. 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 5,118 net MW as of December 31, 2017. Nearly all of these assets sell substantially all of its output pursuant to long-term offtake agreements with creditworthy counterparties. The weighted average remaining contract duration of these offtake agreements was approximately 15 years as of December 31, 2017, based on CAFD. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,319 net MWt and electric generation capacity of 123 net MW. These thermal infrastructure assets provide steam, hot and/or chilled water, and, in some instances, electricity, to commercial businesses, universities, hospitals and governmental units in multiple locations, principally through long-term contracts or pursuant to rates regulated by state utility commissions.

A complete listing of the Company's interests in facilities, operations and/or projects owned or leased as of December 31, 2017 can be found in Item 2 — Properties.

History

On July 22, 2013, Yield, Inc. closed the initial public offering of 22,511,250 shares of its Class A common stock for net proceeds, after deducting underwriting discounts, of $468 million, of which Yield, Inc. used $395 million to purchase 19,011,250 of the Company's Class A units from NRG and $73 million to purchase 3,500,000 of the Company's Class A units directly from the Company. On July 29, 2014, Yield, Inc. issued 12,075,000 shares of Class A common stock for net proceeds, after underwriting discounts and expenses, of $630 million and utilized the proceeds of the offering to acquire 12,075,000 additional Class A units of the Company.

Effective May 14, 2015, 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 Yield, Inc.'s outstanding Class A common stock and Class B common stock, respectively, through a stock split. The stock split is referred to as the Recapitalization. Contemporaneously with Yield, Inc.’s Recapitalization, each Class A unit of the Company was automatically reclassified into one Class A unit and one Class C unit and each Class B unit of the Company was automatically reclassified into one Class B unit and one Class D unit. On June 29, 2015, Yield, Inc. issued 28,198,000 shares of Class C common stock for net proceeds of $599 million and utilized the proceeds of the offering to acquire 28,198,000 Class C units of the Company.

As of December 31, 2017, NRG owned 42,738,750 of each of the Company's Class B units and Class D units and Yield, Inc. owned 34,586,250 of the Company's Class A units and 64,717,087 of the Company's Class C units. Yield, Inc., through its holdings of Class A units and Class C units, has a 53.7% economic interest in the Company. Yield, Inc. consolidates the results of the Company through its controlling interest as sole managing member. NRG, through its holdings of Class B units and Class D units, has a 46.3% economic interest in the Company.

The Company is a holding company for the companies that directly and indirectly own and operate Yield, Inc.'s business. As of December 31, 2017, NRG continues to control Yield, Inc., and Yield, Inc. in turn, as the sole managing member of the Company, controls the Company and its subsidiaries.

The diagram below depicts the Company’s organizational structure as of December 31, 2017:

https://cdn.kscope.io/7099ca460dbfd235dcdf54b42d2e49c3-yieldorgpic02.jpg

Strategic Sponsorship with Global Infrastructure Partners

On February 6, 2018, Global Infrastructure Partners, or GIP, entered into a purchase and sale agreement with NRG, or the NRG Transaction, for the acquisition of NRG’s full ownership interest in NRG Yield, Inc. and NRG’s renewable energy development and operations platform. The NRG Transaction is subject to certain closing conditions, including customary legal and regulatory approvals. The Company expects the NRG Transaction to close in the second half of 2018.

In connection with the NRG Transaction, the Company entered into a Consent and Indemnity Agreement with NRG and GIP setting forth key terms and conditions of the Company's consent to the NRG Transaction. Key provisions of the Consent and Indemnity Agreement include:

Minimized impact to CAFD from potential change in control costs — No more than $10 million in reduced annual CAFD on a recurring basis that would result from changes in the Company's cost structure or any impact from various consents.

Enhanced ROFO pipeline — Upon closing, the Company will enter into a new ROFO agreement with GIP that adds 550 MW to the current pipeline through the operational 150 MW Langford Wind project and the 400 MW Mesquite Star Wind project which is under development. The NRG ROFO Agreement will be amended to remove the Ivanpah solar facility.

Financial cooperation and support — GIP has arranged a $1.5 billion backstop credit facility to manage any change of control costs associated with the Company's corporate debt. GIP has also committed to provide up to $400 million in financial support, if necessary, for the purchase of the Carlsbad Energy Center.

Voting and Governance Agreement — As part of the NRG Transaction, the parties have agreed to enter into a voting and governance agreement, which would provide that:


•	the Chief Executive Officer of Yield, Inc. will at all times be a full-time Yield, Inc. employee appointed by the Board of Directors, or the Board, of Yield, Inc.;


•	the parties thereto will use their commercially reasonable efforts to submit to Yield, Inc.’s stockholders at Yield, Inc.'s 2019 Annual Meeting of Stockholders a charter amendment to classify the Board into two classes (with the independent directors and directors designated by an affiliate of GIP allocated across the two classes); and


•	the Board will be expanded to nine members at the closing of the NRG Transaction, comprised at that date of five directors designated by GIP, three independent directors and Yield, Inc.’s Chief Executive Officer.

Business Strategy

The Company's primary business strategy is to focus on the acquisition and ownership of assets with predictable, long-term cash flows in order that it may be able to increase the cash distributions to Yield, Inc. and NRG over time without compromising the ongoing stability of the business. The Company's plan for executing this strategy includes the following key components:

Focus on contracted renewable energy and conventional generation and thermal infrastructure assets. The Company owns and operates utility scale and distributed renewable energy and natural gas-fired generation, thermal and other infrastructure assets with proven technologies, low operating risks and stable cash flows. The Company believes by focusing on this core asset class and leveraging its industry knowledge, it will maximize its strategic opportunities, be a leader in operational efficiency and maximize its overall financial performance.

Growing the business through acquisitions of contracted operating assets. The Company believes that its base of operations and relationship with NRG provide a platform in the conventional and renewable power generation and thermal sectors for strategic growth through cash accretive and tax advantaged acquisitions complementary to its existing portfolio. In addition to acquiring renewable generation, conventional generation and thermal infrastructure assets from third parties where the Company believes its knowledge of the market and operating expertise provides it with a competitive advantage, the Company entered into a Right of First Offer Agreement with NRG, or the NRG ROFO Agreement. Under the NRG ROFO Agreement, NRG has granted the Company and its affiliates a right of first offer on any proposed sale, transfer or other disposition of certain assets of NRG until February 24, 2022. NRG is not obligated to sell the remaining NRG ROFO Assets to the Company and, if offered by NRG, the Company cannot be sure whether these assets will be offered on acceptable terms, or that the Company will choose to consummate such acquisitions. The assets listed in the table below represent the NRG ROFO Assets:



Asset	Fuel Type	Rated Capacity (MW)^(a)	COD
Agua Caliente	Solar	102	2014
Ivanpah	Solar	196	2013
Hawaii^(b)	Solar	80	2019
Distributed Solar (up to $190 million of equity in distributed solar generation portfolio(s)^(b)	Solar	various	various
Buckthorn Solar^(c)	Solar	154	2018
Carlsbad^(d)	Conventional	527	2018
Puente/Mandalay^(e)	Conventional	Project not expected to move forward
Community	Wind	Sold to third party
Jeffers	Wind	Sold to third party
Minnesota Portfolio	Wind	Sold to third party

^(a)Represents the maximum, or rated, electricity generating capacity of the facility in MW multiplied by NRG's percentage ownership interest in the facility as of December 31, 2017.

^(b)Hawaii and Distributed Solar are part of the NRG ROFO Agreement. These are not expected to be offered by NRG prior to consummation of the NRG Transaction and, at that time, would become part of a new ROFO Agreement with GIP.

^(c)The transaction is expected to close in the first quarter of 2018.

^(d)The transaction is expected to close in the fourth quarter of 2018 and is contingent upon the consummation of the NRG Transaction. Reflects capacity per the Power Purchase & Tolling Agreement with San Diego Gas & Electric; actual tested capacity is expected to be 530 MW.

^(e)On November 3, 2017, the California Energy Commission suspended the permitting process for the Puente Power Project after two commissioners issued a statement stating their intention to deny the permit. If the CEC formally denies a permit for the Puente Power Project, then the project will not move forward.

Upon closing of the NRG Transaction, the Company will enter into a new ROFO agreement with GIP that adds 550 MW to the current pipeline through the operational 150 MW Langford Wind project and the 400 MW Mesquite Star Wind project which is under development. The NRG ROFO Agreement will be amended to remove the Ivanpah solar facility.

Primary focus on North America. The Company intends to primarily focus its investments in North America (including the unincorporated territories of the U.S.). The Company believes that industry fundamentals in North America present it with significant opportunity to acquire renewable, natural gas-fired generation and thermal infrastructure assets, without creating significant exposure to currency and sovereign risk. By primarily focusing its efforts on North America, the Company believes it will best leverage its regional knowledge of power markets, industry relationships and skill sets to maximize the performance of the Company.

Competition

Power generation is a capital-intensive business with numerous and diverse industry participants. The Company competes on the basis of the location of its plants and on the basis of contract price and terms of individual projects. Within the power industry, there is a wide variation in terms of the capabilities, resources, nature and identity of the companies with whom the Company competes with depending on the market. Competitors for energy supply are utilities, independent power producers and other providers of distributed generation. The Company also competes to acquire new projects with renewable developers who retain renewable power plant ownership, independent power producers, financial investors and other dividend, growth-oriented companies. Competitive conditions may be substantially affected by capital market conditions and by various forms of energy legislation and regulation considered by federal, state and local legislatures and administrative agencies, including tax policy. Such laws and regulations may substantially increase the costs of acquiring, constructing and operating projects, and it could be difficult for the Company to adapt to and operate under such laws and regulations.

The Company's thermal business has certain cost efficiencies that may form barriers to entry. Generally, there is only one district energy system in a given territory, for which the only competition comes from on-site systems. While the district energy system can usually make an effective case for the efficiency of its services, some building owners nonetheless may opt for on-site systems, either due to corporate policies regarding allocation of capital, unique situations where an on-site system might in fact prove more efficient, or because of previously committed capital in systems that are already on-site. Growth in existing district energy systems generally comes from new building construction or existing building conversions within the service territory of the district energy provider.

Competitive Strengths

Stable, high quality cash flows. The Company's facilities have a stable, predictable cash flow profile consisting of predominantly long-life electric generation assets that sell electricity under long-term fixed priced contracts or pursuant to regulated rates with investment grade and certain other credit-worthy counterparties. Additionally, the Company's facilities have minimal fuel risk. For the Company's conventional assets, fuel is provided by the toll counterparty or the cost thereof is a pass-through cost under the CfD. Renewable facilities have no fuel costs, and most of the Company's thermal infrastructure assets have contractual or regulatory tariff mechanisms for fuel cost recovery. The offtake agreements for the Company's conventional and renewable generation facilities have a weighted-average remaining duration of approximately 15 years as of December 31, 2017, based on CAFD, providing long-term cash flow stability. The Company's generation offtake agreements with counterparties for whom credit ratings are available have a weighted-average Moody’s rating of A3 based on rated capacity under contract. All of the Company's assets are in the U.S. and accordingly have no currency or repatriation risks.

High quality, long-lived assets with low operating and capital requirements. The Company benefits from a portfolio of relatively younger assets, other than thermal infrastructure assets. The Company's assets are comprised of proven and reliable technologies, provided by leading original solar and wind equipment manufacturers such as General Electric, Siemens AG, SunPower Corporation, or SunPower, First Solar Inc., or First Solar, Vestas, Suzlon and Mitsubishi. Given the modern nature of the portfolio, which includes a substantial number of relatively low operating and maintenance cost solar and wind generation assets, the Company expects to achieve high fleet availability and expend modest maintenance-related capital expenditures. Additionally, with the support of services provided by NRG, the Company expects to continue to implement the same rigorous preventative operating and management practices that NRG uses across its fleet of assets.

Significant scale and diversity. The Company owns and operates a large and diverse portfolio of contracted electric generation and thermal infrastructure assets. As of December 31, 2017, the Company's 5,118 net MW contracted generation portfolio benefits from significant diversification in terms of technology, fuel type, counterparty and geography. The Company's thermal business consists of twelve operations, seven of which are district energy centers that provide steam and chilled water to approximately 695 customers, and five of which provide generation. The Company believes its scale and access to best practices across the fleet improves its business development opportunities through enhanced industry relationships, reputation and understanding of regional power market dynamics. Furthermore, the Company's diversification reduces its operating risk profile and reliance on any single market.

Relationship with NRG. The Company believes its relationship with NRG, a leading competitive power generator in the U.S., provides significant benefits to the Company, including access to the significant resources of NRG to support its operational, financial, legal, regulatory and environmental functions.

Relationship with GIP. The Company believes its potential relationship with GIP, should the NRG Transaction be consummated, may provide significant benefits to the Company. GIP is an independent infrastructure fund with over $45 billion in assets under management that invests in infrastructure assets and businesses in both OECD and select emerging market countries. GIP has a strong track record of investment and value creation in the renewable energy sector. Additionally, GIP has extensive experience with publicly traded yield vehicles and development platforms, ranging from Europe's first application of a yield company/development company model to the largest renewable platform in Asia-Pacific.

Environmentally well-positioned portfolio of assets. The Company's portfolio of electric generation assets consists of 3,173 net MW of renewable generation capacity that are non-emitting sources of power generation. The Company's conventional assets consist of the dual fuel-fired GenConn assets as well as the Marsh Landing and Walnut Creek simple cycle natural gas-fired peaking generation facilities and the El Segundo combined cycle natural gas-fired peaking facility. The Company does not anticipate having to expend any significant capital expenditures in the foreseeable future to comply with current environmental regulations applicable to its generation assets. Taken as a whole, the Company believes its strategy will be a net beneficiary of current and potential environmental legislation and regulatory requirements that may serve as a catalyst for capacity retirements and improve market opportunities for environmentally well-positioned assets like the Company's assets once its current offtake agreements expire.

Thermal infrastructure business has high entry costs. Significant capital has been invested to construct the Company's thermal infrastructure assets, serving as a barrier to entry in the markets in which such assets operate. As of December 31, 2017, the Company's thermal gross property, plant, and equipment was approximately $473 million. The Company's thermal district energy centers are located in urban city areas, with the chilled water and steam delivery systems located underground. Constructing underground delivery systems in urban areas requires long lead times for permitting, rights of way and inspections and is costly. By contrast, the incremental cost to add new customers in existing markets is relatively low. Once thermal infrastructure is established, the Company believes it has the ability to retain customers over long periods of time and to compete effectively for additional business against stand-alone on-site heating and cooling generation facilities. Installation of stand-alone equipment can require significant modification to a building as well as significant space for equipment and funding for capital expenditures. The Company's system technologies often provide economies of scale in terms of fuel procurement, ability to switch between multiple types of fuel to generate thermal energy, and fuel conversion efficiency.

Segment Review

The following tables summarize the Company's operating revenues, net income (loss) and assets by segment for the years ended December 31, 2017, 2016 and 2015, as discussed in Item 15 — Note 12, Segment Reporting, to the Consolidated Financial Statements. All amounts have been recast to include the effect of the acquisitions of the Drop Down Assets, which 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).



	Year ended December 31, 2017
(In millions)	Conventional Generation		Renewables		Thermal		Corporate			Total
Operating revenues	$	336	$	501	$	172	$	—		$	1,009
Net income (loss)	120		9		25		(92		)	62
Total assets	1,897		5,811		422		24			8,154



	Year ended December 31, 2016
(In millions)	Conventional Generation		Renewables			Thermal		Corporate			Total
Operating revenues	$	333	$	532		$	170	$	—		$	1,035
Net income (loss)	153		(86		)	29		(81		)	15
Total assets	1,993		6,114			426		212			8,745



	Year ended December 31, 2015
(In millions)	Conventional Generation		Renewables			Thermal		Corporate			Total
Operating revenues	$	336	$	458		$	174	$	—		$	968
Net income (loss)	156		(18		)	22		(65		)	95

Government Incentives

Government incentives, including PTCs and ITCs, can enhance the economics of the Company's generating assets and investments by providing, for example, loan guarantees, cash grants, favorable tax treatment, favorable depreciation rules or other incentives. The Company cannot predict the effects that the current U.S. presidential administration will have on government incentives.

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 agencies 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 PUCT.

FERC

FERC, among other things, regulates the transmission and the wholesale sale of electricity in interstate commerce under the authority of the FPA. The transmission of electric energy occurring wholly within ERCOT is not subject to FERC’s jurisdiction under Sections 203 or 205 of the FPA. Under existing regulations, FERC determines whether an entity owning a generation facility is an EWG, as defined in the PUHCA. FERC also determines whether a generation facility meets the ownership and technical criteria of a QF under the PURPA. Each of the Company’s non-ERCOT generating facilities qualifies as an EWG.

The FPA gives FERC exclusive rate-making jurisdiction over the wholesale sale of electricity and transmission of electricity in interstate commerce of public utilities (as defined by the FPA). Under the FPA, FERC, with certain exceptions, regulates the owners of facilities used for the wholesale sale of electricity or transmission in interstate commerce as public utilities, and establishes market rules that are just and reasonable.

Public utilities are required to obtain FERC’s acceptance, pursuant to Section 205 of the FPA, of their rate schedules for the wholesale sale of electricity. All of the Company’s non-QF generating entities located outside of ERCOT make sales of electricity pursuant to market-based rates, as opposed to traditional cost-of-service regulated rates. Every three years FERC will conduct a review of the Company’s market based rates and potential market power on a regional basis.

In accordance with the Energy Policy Act of 2005, FERC has approved the NERC as the national Energy Reliability Organization, or ERO. As the ERO, NERC is responsible for the development and enforcement of mandatory reliability standards for the wholesale electric power system. In addition to complying with NERC requirements, each entity must comply with the requirements of the regional reliability entity for the region in which it is located.

The PURPA was passed in 1978 in large part to promote increased energy efficiency and development of independent power producers. The PURPA created QFs to further both goals, and FERC is primarily charged with administering the PURPA as it applies to QFs. Certain QFs are exempt from regulation, either in whole or in part, under the FPA as public utilities.

The PUHCA provides FERC with certain authority over and access to books and records of public utility holding companies not otherwise exempt by virtue of their ownership of EWGs, QFs, and Foreign Utility Companies. The Company is exempt from many of the accounting, record retention, and reporting requirements of the PUHCA.

Environmental Matters

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 regarding the protection of wildlife, including migratory birds, eagles, threatened and endangered species. Federal and state environmental laws have historically become more stringent over time, although this trend could change with respect to federal laws under the current U.S. presidential administration.

In October 2015, the EPA finalized the Clean Power Plan, or CPP, addressing GHG emissions from existing EGUs. On February 9, 2016, the U.S. Supreme Court stayed the CPP. The D.C. Circuit heard oral argument on the legal challenges to the CPP in September 2016. At the EPA's request, the D.C. Circuit agreed on April 28, 2017 to hold the case in abeyance. On October 16, 2017, the EPA proposed a rule to repeal the CPP. Accordingly, the Company believes the CPP is not likely to survive.

Customers

The Company sells its electricity and environmental attributes, including RECs, primarily to local utilities under long-term, fixed-price PPAs. During the year ended December 31, 2017, the Company derived approximately 41% of its consolidated revenue from Southern California Edison, or SCE, and approximately 23% of its consolidated revenue from Pacific Gas and Electric, or PG&E.

Employees

The Company employs Christopher Sotos as its President and Chief Executive Officer and Chad Plotkin as its Senior Vice President and Chief Financial Officer. As of December 31, 2017, other than Messrs. Sotos and Plotkin, the Company did not employ any other employees. The majority of personnel who manage operations of the Company are employees of NRG or third parties managed by NRG, and their services are provided for the Company's benefit under the Management Services Agreement and project operations and maintenance agreements with NRG as described in Item 15 — Note 13, Related Party Transactions, to the Consolidated Financial Statements.

Available Information

The Company's annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to section 13(a) or 15(d) of the Exchange Act are available free of charge through Yield, Inc.'s website, www.nrgyield.com, as soon as reasonably practicable after they are electronically filed with, or furnished to, the SEC. The Company also routinely posts press releases, presentations, webcasts, and other information regarding the Company on Yield, Inc.'s website. The information posted on Yield, Inc.'s website is not a part of this report.

Item 1A — Risk Factors

Risks Related to the Proposed NRG Transaction

The Company may not realize the anticipated benefits of the NRG Transaction.

On February 6, 2018, Global Infrastructure Partners, or GIP, entered into a purchase and sale agreement with NRG for the acquisition of NRG’s full ownership interest in the Company and NRG’s renewable energy development and operations platform. Also on February 6, 2018, the Company entered into a consent and indemnity agreement with NRG and GIP in connection with the purchase and sale agreement between NRG and GIP. The consent and indemnity agreement and the purchase and sale agreement are collectively referred to as the NRG Transaction. Consummation of the NRG Transaction is subject to a number of conditions, including receipt of certain contractual consents and regulatory approvals from certain regulatory agencies, including approval by FERC and approvals from certain state regulatory agencies. While the parties have begun the process of notifying agencies and obtaining regulatory approvals and consents, there is no assurance that the parties will be able to obtain the requisite regulatory approvals or consents to satisfy the closing conditions. Additionally, the NRG Transaction requires the Company’s consent which is conditioned upon a number of items, all of which may not be met on a timely basis, or at all.

If the NRG Transaction is consummated, GIP may exercise substantial influence over the Company’s policies and procedures and exercise substantial influence over the Company’s Board, management and the types of third party acquisitions the Company makes. The Company may not identify future acquisitions or be able to secure financing on attractive terms or at all for future acquisitions and the Company may not realize the anticipated benefits of the financing support to be provided by GIP, which includes a $1.5 billion backstop credit facility to manage any change-of-control costs associated with the Company’s corporate debt and up to $400 million in financing support for the Company’s acquisition of the Carlsbad Energy Center. Further, GIP may not be able to maintain the Company’s current relationships with customers, counterparties, suppliers, lenders and other third

parties. Uncertainty about the effect of the NRG Transaction may negatively affect the Company’s relationship with its counterparties and have a significant impact on the Company’s business. The foregoing risks may adversely affect the Company’s operational performance or limit the Company’s growth prospects, including its ability to grow its dividend per share.

Following the consummation of the NRG Transaction, GIP and its affiliates will control the Company and have the ability to designate a majority of the members of Yield, Inc.'s Board.

The governance agreements to be entered into among NRG, the Company, GIP and its affiliates in connection with the NRG Transaction provide GIP the ability to designate a majority of Yield, Inc.’s Board to the Company’s Corporate Governance, Conflicts and Nominating Committee for nomination for election by Yield, Inc.’s stockholders and also require that the Company and GIP use their commercially reasonable efforts to submit to Yield, Inc.’s stockholders at Yield, Inc.’s 2019 Annual Meeting of Stockholders a charter amendment to classify Yield, Inc.’s Board into two classes (with the independent directors and directors designated by GIP allocated across the two classes). Due to such agreements and GIP's approximate 55.1% combined voting power in Yield, Inc. following the completion of the NRG Transaction, the ability of other holders of Yield, Inc.’s Class A and Class C common stock to exercise control over the corporate governance of the Company will be limited. In addition, due to its approximate 55.1% combined voting power in the Company following the completion of the NRG Transaction, GIP and its affiliates will have a substantial influence on Yield, Inc.’s affairs and its voting power will constitute a large percentage of any quorum of Yield, Inc.’s stockholders voting on any matter requiring the approval of Yield, Inc.’s stockholders, including the classification of Yield, Inc.'s Board of Directors. GIP may hold certain interests that are different from those of the Company or other holders of Yield, Inc.'s Class A and Class C common stock and there is no assurance that GIP will exercise its control over the Company in a manner that is consistent with the Company’s interests or those of the holders of Yield, Inc.'s Class A and Class C common stock.

Risks Related to the Company's Business

Certain facilities are newly constructed and may not perform as expected.

Certain of the Company's conventional and renewable assets are newly constructed. The ability of these facilities to meet the Company's performance expectations is subject to the risks inherent in newly constructed power generation facilities and the construction of such facilities, including, but not limited to, degradation of equipment in excess of the Company's expectations, system failures, and outages. The failure of these facilities to perform as the Company expects could have a material adverse effect on the Company's business, financial condition, results of operations, cash flows and its ability to pay distributions to Yield, Inc. and NRG.

Pursuant to the Company's cash distribution policy, the Company intends to distribute a significant amount of the CAFD through regular quarterly distributions, and the Company's ability to grow and make acquisitions through cash on hand could be limited.

The Company expects to distribute a significant amount of the CAFD each quarter and to rely primarily upon external financing sources, including the issuance of debt and equity securities and, if applicable, borrowings under the Company's revolving credit facility to fund acquisitions and growth capital expenditures. The Company may be precluded from pursuing otherwise attractive acquisitions if the projected short-term cash flow from the acquisition or investment is not adequate to service the capital raised to fund the acquisition or investment, after giving effect to the Company's available cash reserves. The incurrence of bank borrowings or other debt by NRG Yield Operating LLC or by the Company's project-level subsidiaries to finance the Company’s growth strategy will result in increased interest expense and the imposition of additional or more restrictive covenants, which, in turn, may impact the cash distributions the Company makes to Yield, Inc. and NRG.

The Company may not be able to effectively identify or consummate any future acquisitions on favorable terms, or at all.

The Company's business strategy includes growth through the acquisitions of additional generation assets (including through corporate acquisitions). This strategy depends on the Company’s ability to successfully identify and evaluate acquisition opportunities and consummate acquisitions on favorable terms. However, the number of acquisition opportunities is limited. In addition, the Company will compete with other companies for these limited acquisition opportunities, which may increase the Company’s cost of making acquisitions or cause the Company to refrain from making acquisitions at all. Some of the Company’s competitors for acquisitions are much larger than the Company with substantially greater resources. These companies may be able to pay more for acquisitions and may be able to identify, evaluate, bid for and purchase a greater number of assets than the Company’s financial or human resources permit. If the Company is unable to identify and consummate future acquisitions, it will impede the Company’s ability to execute its growth strategy and limit the Company’s ability to increase the amount of dividends paid to holders of Yield, Inc.'s common stock.

Furthermore, the Company’s ability to acquire future renewable facilities may depend on the viability of renewable assets generally. These assets currently are largely contingent on public policy mechanisms including ITCs, cash grants, loan guarantees, accelerated depreciation, RPS and carbon trading plans. These mechanisms have been implemented at the state and federal levels to support the development of renewable generation, demand-side and smart grid and other clean infrastructure technologies. The availability and continuation of public policy support mechanisms will drive a significant part of the economics and viability of the Company’s growth strategy and expansion into clean energy investments.

The Company’s ability to effectively consummate future acquisitions will also depend on the Company’s ability to arrange the required or desired financing for acquisitions.

The Company may not have sufficient availability under the Company’s credit facilities or have access to project-level financing on commercially reasonable terms when acquisition opportunities arise. An inability to obtain the required or desired financing could significantly limit the Company’s ability to consummate future acquisitions and effectuate the Company’s growth strategy. If financing is available, utilization of the Company’s credit facilities or project-level financing for all or a portion of the purchase price of an acquisition could significantly increase the Company’s interest expense, impose additional or more restrictive covenants and reduce CAFD. The Company’s ability to consummate future acquisitions may also depend on the Company’s ability to obtain any required regulatory approvals for such acquisitions, including, but not limited to, approval by FERC under Section 203 of the FPA.

Finally, the acquisition of companies and assets are subject to substantial risks, including the failure to identify material problems during due diligence (for which the Company may not be indemnified post-closing), the risk of over-paying for assets (or not making acquisitions on an accretive basis) and the ability to retain customers. Further, the integration and consolidation of acquisitions requires substantial human, financial and other resources and, ultimately, the Company's acquisitions may divert management’s attention from the Company's existing business concerns, disrupt the Company's ongoing business or not be successfully integrated. There can be no assurances that any future acquisitions will perform as expected or that the returns from such acquisitions will support the financing utilized to acquire them or maintain them. As a result, the consummation of acquisitions may have a material adverse effect on the Company's business, financial condition, results of operations, cash flows and ability to pay distributions to Yield, Inc. and NRG.

Even if the Company consummates acquisitions that it believes will be accretive to CAFD, those acquisitions may decrease CAFD as a result of incorrect assumptions in the Company’s evaluation of such acquisitions, unforeseen consequences or other external events beyond the Company’s control.

The acquisition of existing generation assets involves the risk of overpaying for such projects (or not making acquisitions on an accretive basis) and failing to retain the customers of such projects. While the Company will perform due diligence on prospective acquisitions, the Company may not discover all potential risks, operational issues or other issues in such generation assets. Further, the integration and consolidation of acquisitions require substantial human, financial and other resources and, ultimately, the Company’s acquisitions may divert the Company’s management’s attention from its existing business concerns, disrupt its ongoing business or not be successfully integrated. Future acquisitions might not perform as expected or the returns from such acquisitions might not support the financing utilized to acquire them or maintain them. A failure to achieve the financial returns the Company expects when it acquires generation assets could have a material adverse effect on the Company’s ability to grow its business and make cash distributions to its unitholders. Any failure of the Company’s acquired generation assets to be accretive or difficulty in integrating such acquisition into the Company’s business could have a material adverse effect on the Company’s ability to grow its business and make cash distributions to its unitholders.

The Company’s indebtedness could adversely affect its ability to raise additional capital to fund the Company’s operations or pay distributions. It could also expose the Company to the risk of increased interest rates and limit the Company’s ability to react to changes in the economy or the Company’s industry as well as impact the Company’s results of operations, financial condition and cash flows.

As of December 31, 2017, the Company had approximately $5,899 million of total consolidated indebtedness, $4,376 million of which was incurred by the Company's non-guarantor subsidiaries. In addition, the Company’s share of its unconsolidated affiliates’ total indebtedness and letters of credit outstanding as of December 31, 2017, totaled approximately $777 million and $98 million, respectively (calculated as the Company’s unconsolidated affiliates’ total indebtedness as of such date multiplied by the Company’s percentage membership interest in such assets). The Company’s substantial debt could have important negative consequences on the Company’s financial condition, including:


•	increasing the Company’s vulnerability to general economic and industry conditions;


•	requiring a substantial portion of the Company’s cash flow from operations to be dedicated to the payment of principal and interest on the Company’s indebtedness, therefore reducing the Company’s ability to pay distributions to Yield, Inc. and NRG or to use the Company’s cash flow to fund its operations, capital expenditures and future business opportunities;


•	limiting the Company’s ability to enter into long-term power sales or fuel purchases which require credit support;


•	limiting the Company’s ability to fund operations or future acquisitions;


•	restricting the Company’s ability to make certain distributions to Yield, Inc. and NRG and the ability of the Company’s subsidiaries to make certain distributions to it, in light of restricted payment and other financial covenants in the Company’s credit facilities and other financing agreements;


•	exposing the Company to the risk of increased interest rates because certain of the Company’s borrowings, which may include borrowings under the Company’s revolving credit facility, are at variable rates of interest;


•	limiting the Company’s ability to obtain additional financing for working capital including collateral postings, capital expenditures, debt service requirements, acquisitions and general corporate or other purposes; and


•	limiting the Company’s ability to adjust to changing market conditions and placing it at a competitive disadvantage compared to the Company’s competitors who have less debt.

The Company's revolving credit facility contains financial and other restrictive covenants that limit the Company’s ability to return capital to stockholders or otherwise engage in activities that may be in the Company’s long-term best interests. The Company’s inability to satisfy certain financial covenants could prevent the Company from paying cash distributions, and the Company’s failure to comply with those and other covenants could result in an event of default which, if not cured or waived, may entitle the related lenders to demand repayment or enforce their security interests, which could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flows. In addition, failure to comply with such covenants may entitle the related lenders to demand repayment and accelerate all such indebtedness.

The agreements governing the Company’s project-level financing contain financial and other restrictive covenants that limit the Company’s project subsidiaries’ ability to make distributions to the Company or otherwise engage in activities that may be in the Company’s long-term best interests. The project-level financing agreements generally prohibit distributions from the project entities to the Company unless certain specific conditions are met, including the satisfaction of certain financial ratios. The Company’s inability to satisfy certain financial covenants may prevent cash distributions by the particular project(s) to it and, the Company’s failure to comply with those and other covenants could result in an event of default which, if not cured or waived may entitle the related lenders to demand repayment or enforce their security interests, which could have a material adverse effect on the Company’s business, results of operations and financial condition. In addition, failure to comply with such covenants may entitle the related lenders to demand repayment and accelerate all such indebtedness. If the Company is unable to make distributions from the Company’s project-level subsidiaries, it would likely have a material adverse effect on the Company’s ability to pay distributions to Yield, Inc. and NRG.

Letter of credit facilities to support project-level contractual obligations generally need to be renewed after five to seven years, at which time the Company will need to satisfy applicable financial ratios and covenants. If the Company is unable to renew the Company’s letters of credit as expected or replace them with letters of credit under different facilities on favorable terms or at all, the Company may experience a material adverse effect on its business, financial condition, results of operations and cash flows. Furthermore, such inability may constitute a default under certain project-level financing arrangements, restrict the ability of the project-level subsidiary to make distributions to it and/or reduce the amount of cash available at such subsidiary to make distributions to the Company.

In addition, the Company’s ability to arrange financing, either at the corporate level or at a non-recourse project-level subsidiary, and the costs of such capital, are dependent on numerous factors, including:


•	general economic and capital market conditions;


•	credit availability from banks and other financial institutions;


•	investor confidence in the Company, its partners, Yield, Inc. (as the Company's sole managing member), NRG (as Yield Inc.’s principal stockholder, on a combined voting basis, and manager under the Management Services Agreement), or GIP, as successor to NRG's interests in the Company if the NRG Transaction is consummated, and the regional wholesale power markets;


•	the Company’s financial performance and the financial performance of the Company subsidiaries;


•	the Company’s level of indebtedness and compliance with covenants in debt agreements;


•	maintenance of acceptable project credit ratings or credit quality;


•	cash flow; and


•	provisions of tax and securities laws that may impact raising capital.

The Company may not be successful in obtaining additional capital for these or other reasons. Furthermore, the Company may be unable to refinance or replace project-level financing arrangements or other credit facilities on favorable terms or at all upon the expiration or termination thereof. The Company's failure, or the failure of any of the Company’s projects, to obtain additional capital or enter into new or replacement financing arrangements when due may constitute a default under such existing indebtedness and may have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.

Certain of the Company's long-term bilateral contracts result from state-mandated procurements and could be declared invalid by a court of competent jurisdiction.

A significant portion of the Company's revenues are derived from long-term bilateral contracts with utilities that are regulated by their respective states, and have been entered into pursuant to certain state programs. Certain long-term contracts that other companies have with state-regulated utilities have been challenged in federal court and have been declared unconstitutional on the grounds that the rate for energy and capacity established by the contracts impermissibly conflicts with the rate for energy and capacity established by FERC pursuant to the FPA. If certain of the Company's state-mandated agreements with utilities are ever held to be invalid, the Company may be unable to replace such contracts, which could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.

The generation of electric energy from solar and wind energy sources depends heavily on suitable meteorological conditions.

If solar or wind conditions are unfavorable, the Company's electricity generation and revenue from renewable generation facilities may be substantially below the Company's expectations. The electricity produced and revenues generated by a solar or wind energy generation facility is highly dependent on suitable solar or wind conditions, as applicable, and associated weather conditions, which are beyond the Company's control. Furthermore, components of the Company's systems, such as solar panels and inverters, could be damaged by severe weather, such as hailstorms or tornadoes. In addition, replacement and spare parts for key components may be difficult or costly to acquire or may be unavailable. Unfavorable weather and atmospheric conditions could impair the effectiveness of the Company's assets or reduce their output beneath their rated capacity or require shutdown of key equipment, impeding operation of the Company's renewable assets. In addition, climate change may have the long-term effect of changing wind patterns at our projects. Changing wind patterns could cause changes in expected electricity generation. These events could also degrade equipment or components and the interconnection and transmission facilities’ lives or maintenance costs.

Although the Company bases its investment decisions with respect to each renewable generation facility on the findings of related wind and solar studies conducted on-site prior to construction or based on historical conditions at existing facilities, actual climatic conditions at a facility site, particularly wind conditions, may not conform to the findings of these studies and may be affected by variations in weather patterns, including any potential impact of climate change. Therefore, the Company's solar and wind energy facilities may not meet anticipated production levels or the rated capacity of the Company's generation assets, which could adversely affect the business, financial condition, results of operations and cash flows.

Operation of electric generation facilities involves significant risks and hazards customary to the power industry that could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.

The ongoing operation of the Company's facilities involves risks that include the breakdown or failure of equipment or processes or performance below expected levels of output or efficiency due to wear and tear, latent defect, design error or operator error or force majeure events, among other things. Operation of the Company's facilities also involves risks that the Company will be unable to transport its products to its customers in an efficient manner due to a lack of transmission capacity. Unplanned outages of generating units, including extensions of scheduled outages due to mechanical failures or other problems, occur from time to time and are an inherent risk of the business. Unplanned outages typically increase operation and maintenance expenses, capital expenditures and may reduce revenues as a result of selling fewer MWh or require the Company to incur significant costs as a result of obtaining replacement power from third parties in the open market to satisfy forward power sales obligations. The Company's inability to operate its electric generation assets efficiently, manage capital expenditures and costs and generate earnings and cash flow from the Company's asset-based businesses could have a material adverse effect on the business, financial condition, results of operations and cash flows. While the Company maintains insurance, obtains warranties from vendors and obligates contractors to meet certain performance levels, the proceeds of such insurance, warranties or performance guarantees may not cover the Company's lost revenues, increased expenses or liquidated damages payments should it experience equipment breakdown or non-performance by contractors or vendors.

Power generation involves hazardous activities, including acquiring, transporting and unloading fuel, operating large pieces of rotating equipment and delivering electricity to transmission and distribution systems.

In addition to natural risks such as earthquake, flood, lightning, hurricane and wind, other hazards, such as fire, explosion, structural collapse and machinery failure are inherent risks in the Company's operations. These and other hazards can cause significant personal injury or loss of life, severe damage to and destruction of property, plant and equipment and contamination of, or damage to, the environment and suspension of operations. The occurrence of any one of these events may result in the Company being named as a defendant in lawsuits asserting claims for substantial damages, including for environmental cleanup costs, personal injury and property damage and fines and/or penalties. The Company maintains an amount of insurance protection that it considers adequate but cannot provide any assurance that the Company's insurance will be sufficient or effective under all circumstances and against all hazards or liabilities to which the Company may be subject. Furthermore, the Company's insurance coverage is subject to deductibles, caps, exclusions and other limitations. A loss for which the Company is not fully insured (which may include a significant judgment against any facility or facility operator) could have a material adverse effect on the Company's business, financial condition, results of operations or cash flows. Further, due to rising insurance costs and changes in the insurance markets, the Company cannot provide any assurance that its insurance coverage will continue to be available at all or at rates or on terms similar to those presently available. Any losses not covered by insurance could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.

Maintenance, expansion and refurbishment of electric generation facilities involve significant risks that could result in unplanned power outages or reduced output.

The Company's facilities may require periodic upgrading and improvement. Any unexpected operational or mechanical failure, including failure associated with breakdowns and forced outages, could reduce the Company's facilities' generating capacity below expected levels, reducing the Company's revenues and jeopardizing the Company's ability to pay distributions to Yield, Inc. and NRG at expected levels or at all. Degradation of the performance of the Company's solar facilities above levels provided for in the related offtake agreements may also reduce the Company's revenues. Unanticipated capital expenditures associated with maintaining, upgrading or repairing the Company's facilities may also reduce profitability.

If the Company makes any major modifications to its conventional power generation facilities, it may be required to install the best available control technology or to achieve the lowest achievable emission rates as such terms are defined under the new source review provisions of the CAA in the future. Any such modifications could likely result in substantial additional capital expenditures. The Company may also choose to repower, refurbish or upgrade its facilities based on its assessment that such activity will provide adequate financial returns. Such facilities require time for development and capital expenditures before commencement of commercial operations, and key assumptions underpinning a decision to make such an investment may prove incorrect, including assumptions regarding construction costs, timing, available financing and future fuel and power prices. These events could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.

Counterparties to the Company's offtake agreements may not fulfill their obligations and, as the contracts expire, the Company may not be able to replace them with agreements on similar terms in light of increasing competition in the markets in which the Company operates.

A significant portion of the electric power the Company generates is sold under long-term offtake agreements with public utilities or industrial or commercial end-users, with a weighted average remaining duration of approximately 15 years based on CAFD. As of December 31, 2017, the largest customers of the Company's power generation assets, including assets in which the Company has less than a 100% membership interest, were SCE and PG&E, which represented 40% and 23%, respectively, of the net electric generation capacity of the Company's facilities.

If, for any reason, any of the purchasers of power under these agreements are unable or unwilling to fulfill their related contractual obligations or if they refuse to accept delivery of power delivered thereunder or if they otherwise terminate such agreements prior to the expiration thereof, the Company's assets, liabilities, business, financial condition, results of operations and cash flows could be materially and adversely affected. Furthermore, to the extent any of the Company's power purchasers are, or are controlled by, governmental entities, the Company's facilities may be subject to legislative or other political action that may impair their contractual performance.

The power generation industry is characterized by intense competition and the Company's electric generation assets encounter competition from utilities, industrial companies and other independent power producers, in particular with respect to uncontracted output. In recent years, there has been increasing competition among generators for offtake agreements and this has contributed to a reduction in electricity prices in certain markets characterized by excess supply above designated reserve margins. In light of these market conditions, the Company may not be able to replace an expiring or terminated agreement with an agreement on equivalent terms and conditions, including at prices that permit operation of the related facility on a profitable basis. In addition, the Company believes many of its competitors have well-established relationships with the Company's current and potential suppliers, lenders and customers and have extensive knowledge of its target markets. As a result, these competitors may be able to respond more quickly to evolving industry standards and changing customer requirements than the Company will be able to. Adoption of technology more advanced than the Company's could reduce its competitors' power production costs resulting in their having a lower cost structure than is achievable with the technologies currently employed by the Company and adversely affect its ability to compete for offtake agreement renewals. If the Company is unable to replace an expiring or terminated offtake agreement, the affected facility may temporarily or permanently cease operations. External events, such as a severe economic downturn, could also impair the ability of some counterparties to the Company's offtake agreements and other customer agreements to pay for energy and/or other products and services received.

The Company's inability to enter into new or replacement offtake agreements or to compete successfully against current and future competitors in the markets in which the Company operates could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows.

The Company’s facilities may operate, wholly or partially, without long-term power sales agreements.

The Company’s facilities may operate without long-term power sales agreements for some or all of their generating capacity and output and therefore be exposed to market fluctuations. Without the benefit of long-term power sales agreements for the facilities, the Company cannot be sure that it will be able to sell any or all of the power generated by the facilities at commercially attractive rates or that the facilities will be able to operate profitably. This could lead to less predictable revenues, future impairments of the Company's property, plant and equipment or to the closing of certain of its facilities, resulting in economic losses and liabilities, which could have a material adverse effect on the Company's results of operations, financial condition or cash flows.

A portion of the steam and chilled water produced by the Company's thermal assets is sold at regulated rates, and the revenue earned by the Company's GenConn assets is established each year in a rate case; accordingly, the profitability of these assets is dependent on regulatory approval.

Approximately 378 net MWt of capacity from certain of the Company's thermal assets are sold at rates approved by one or more federal or state regulatory commissions, including the Pennsylvania Public Utility Commission and the California Public Utilities Commission for the thermal assets. Similarly, the revenues related to approximately 380 MW of capacity from the GenConn assets are established each year by the Connecticut Public Utilities Regulatory Authority. While such regulatory oversight is generally premised on the recovery of prudently incurred costs and a reasonable rate of return on invested capital, the rates that the Company may charge, or the revenue that the Company may earn with respect to this capacity are subject to authorization of the applicable regulatory authorities. There can be no assurance that such regulatory authorities will consider all of the costs to have been prudently incurred or that the regulatory process by which rates or revenues are determined will always result in rates or revenues that achieve full recovery of costs or an adequate return on the Company's capital investments. While the Company's rates and revenues are generally established based on an analysis of costs incurred in a base year, the rates the Company is allowed

to charge, and the revenues the Company is authorized to earn, may or may not match the costs at any given time. If the Company's costs are not adequately recovered through these regulatory processes, it could have a material adverse effect on the business, financial condition, results of operations and cash flows.

Supplier and/or customer concentration at certain of the Company's facilities may expose the Company to significant financial credit or performance risks.

The Company often relies on a single contracted supplier or a small number of suppliers for the provision of fuel, transportation of fuel, equipment, technology and/or other services required for the operation of certain facilities. In addition, certain of the Company's suppliers provide long-term warranties with respect to the performance of their products or services. If any of these suppliers cannot perform under their agreements with the Company, or satisfy their related warranty obligations, the Company will need to utilize the marketplace to provide or repair these products and services. There can be no assurance that the marketplace can provide these products and services as, when and where required. The Company may not be able to enter into replacement agreements on favorable terms or at all. If the Company is unable to enter into replacement agreements to provide for fuel, equipment, technology and other required services, it would seek to purchase the related goods or services at market prices, exposing the Company to market price volatility and the risk that fuel and transportation may not be available during certain periods at any price. The Company may also be required to make significant capital contributions to remove, replace or redesign equipment that cannot be supported or maintained by replacement suppliers, which could have a material adverse effect on the business, financial condition, results of operations, credit support terms and cash flows.

In addition, potential or existing customers at the Company’s district energy centers and combined heat and power plants, or the Energy Centers, may opt for on-site systems in lieu of using the Company’s Energy Centers, either due to corporate policies regarding the allocation of capital, unique situations where an on-site system might in fact prove more efficient, because of previously committed capital in systems that are already on-site, or otherwise. At times, the Company relies on a single customer or a few customers to purchase all or a significant portion of a facility's output, in some cases under long-term agreements that account for a substantial percentage of the anticipated revenue from a given facility.

The failure of any supplier to fulfill its contractual obligations to the Company or the Company’s loss of potential or existing customers could have a material adverse effect on its financial results. Consequently, the financial performance of the Company's facilities is dependent on the credit quality of, and continued performance by, the Company's suppliers and vendors and the Company’s ability to solicit and retain customers.

The Company currently owns, and in the future may acquire, certain assets in which the Company has limited control over management decisions and its interests in such assets may be subject to transfer or other related restrictions.

As described in Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, the Company has limited control over the operation of certain of its assets, because the Company beneficially owns less than a majority of the membership interests in such assets. The Company may seek to acquire additional assets in which it owns less than a majority of the related membership interests in the future. In these investments, the Company will seek to exert a degree of influence with respect to the management and operation of assets in which it owns less than a majority of the membership interests by negotiating to obtain positions on management committees or to receive certain limited governance rights, such as rights to veto significant actions. However, the Company may not always succeed in such negotiations. The Company may be dependent on its co-venturers to operate such assets. The Company's co-venturers may not have the level of experience, technical expertise, human resources management and other attributes necessary to operate these assets optimally. In addition, conflicts of interest may arise in the future between the Company and its stockholders, on the one hand, and the Company's co-venturers, on the other hand, where the Company's co-venturers' business interests are inconsistent with the interests of the Company and its stockholders. Further, disagreements or disputes between the Company and its co-venturers could result in litigation, which could increase expenses and potentially limit the time and effort the Company's officers and directors are able to devote to the business.

The approval of co-venturers may also be required for the Company to receive distributions of funds from assets or to sell, pledge, transfer, assign or otherwise convey its interest in such assets, or for the Company to acquire NRG's interests in such co-ventures as an initial matter. Alternatively, the Company's co-venturers may have rights of first refusal or rights of first offer in the event of a proposed sale or transfer of the Company's interests in such assets. These restrictions may limit the price or interest level for interests in such assets, in the event the Company wants to sell such interests.

Furthermore, certain of the Company's facilities are operated by third-party operators, such as First Solar. To the extent that third-party operators do not fulfill their obligations to manage operations of the facilities or are not effective in doing so, the amount of CAFD may be adversely affected.

The Company's assets are exposed to risks inherent in the use of interest rate swaps and forward fuel purchase contracts and the Company may be exposed to additional risks in the future if it utilizes other derivative instruments.

The Company uses interest rate swaps to manage interest rate risk. In addition, the Company uses forward fuel purchase contracts to hedge its limited commodity exposure with respect to the Company's district energy assets. If the Company elects to enter into such commodity hedges, the related asset could recognize financial losses on these arrangements as a result of volatility in the market values of the underlying commodities or if a counterparty fails to perform under a contract. If actively quoted market prices and pricing information from external sources are not available, the valuation of these contracts would involve judgment or the use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts. If the values of these financial contracts change in a manner that the Company does not anticipate, or if a counterparty fails to perform under a contract, it could harm the business, financial condition, results of operations and cash flows.

The Company's business is subject to restrictions resulting from environmental, health and safety laws and regulations.

The Company is subject to various federal, state and local environmental and health and safety laws and regulations. In addition, the Company may be held primarily or jointly and severally liable for costs relating to the investigation and clean-up of any property where there has been a release or threatened release of a hazardous regulated material as well as other affected properties, regardless of whether the Company knew of or caused the release. In addition to these costs, which are typically not limited by law or regulation and could exceed an affected property's value, the Company could be liable for certain other costs, including governmental fines and injuries to persons, property or natural resources. Further, some environmental laws provide for the creation of a lien on a contaminated site in favor of the government as security for damages and any costs the government incurs in connection with such contamination and associated clean-up. Although the Company generally requires its operators to undertake to indemnify it for environmental liabilities they cause, the amount of such liabilities could exceed the financial ability of the operator to indemnify the Company. The presence of contamination or the failure to remediate contamination may adversely affect the Company's ability to operate the business.

The Company does not own all of the land on which its power generation or thermal assets are located, which could result in disruption to its operations.

The Company does not own all of the land on which its power generation or thermal assets are located and the Company is, therefore, subject to the possibility of less desirable terms and increased costs to retain necessary land use if it does not have valid leases or rights-of-way or if such rights-of-way lapse or terminate. Although the Company has obtained rights to construct and operate these assets pursuant to related lease arrangements, the rights to conduct those activities are subject to certain exceptions, including the term of the lease arrangement. The Company is also at risk of condemnation on land it owns. The loss of these rights, through the Company's inability to renew right-of-way contracts, condemnation or otherwise, may adversely affect the Company's ability to operate its generation and thermal infrastructure assets.

The Company’s use and enjoyment of real property rights for its projects may be adversely affected by the rights of lienholders and leaseholders that are superior to those of the grantors of those real property rights to the Company.

Solar and wind projects generally are, and are likely to be, located on land occupied by the project pursuant to long-term easements and leases. The ownership interests in the land subject to these easements and leases may be subject to mortgages securing loans or other liens (such as tax liens) and other easement and lease rights of third parties (such as leases of oil or mineral rights) that were created prior to the project’s easements and leases. As a result, the project’s rights under these easements or leases may be subject, and subordinate, to the rights of those third parties. The Company performs title searches and obtains title insurance to protect itself against these risks. Such measures may, however, be inadequate to protect the Company against all risk of loss of its rights to use the land on which the wind projects are located, which could have a material adverse effect on the Company’s business, financial condition and results of operations.

The electric generation business is subject to substantial governmental regulation and may be adversely affected by changes in laws or regulations, as well as liability under, or any future inability to comply with, existing or future regulations or other legal requirements.

The Company's electric generation business is subject to extensive U.S. federal, state and local laws and regulations. Compliance with the requirements under these various regulatory regimes may cause the Company to incur significant additional costs, and failure to comply with such requirements could result in the shutdown of the non-complying facility, the imposition of liens, fines, and/or civil or criminal liability. Public utilities under the FPA are required to obtain FERC acceptance of their rate schedules for wholesale sales of electric energy, capacity and ancillary services. Except for generating facilities within the footprint of ERCOT which are regulated by the PUCT, all of the Company’s assets make wholesale sales of electric energy, capacity and ancillary services in interstate commerce and are public utilities for purposes of the FPA, unless otherwise exempt from such status. FERC's orders that grant market-based rate authority to wholesale power marketers reserve the right to revoke or revise that authority if FERC subsequently determines that the seller can exercise market power in transmission or generation, create barriers to entry, or engage in abusive affiliate transactions. In addition, public utilities are subject to FERC reporting requirements that impose administrative burdens and that, if violated, can expose the company to criminal and civil penalties or other risks.

The Company's market-based sales will be subject to certain rules prohibiting manipulative or deceptive conduct, and if any of the Company's generating companies are deemed to have violated those rules, they will be subject to potential disgorgement of profits associated with the violation, penalties, suspension or revocation of market based rate authority. If such generating companies were to lose their market-based rate authority, such companies would be required to obtain FERC's acceptance of a cost-of-service rate schedule and could become subject to the significant accounting, record-keeping, and reporting requirements that are imposed on utilities with cost-based rate schedules. This could have a material adverse effect on the rates the Company is able to charge for power from its facilities.

Most of the Company's assets are operating as EWGs as defined under the PUHCA, or QFs as defined under the PURPA, as amended, and therefore are exempt from certain regulation under the PUHCA and the PURPA. If a facility fails to maintain its status as an EWG or a QF or there are legislative or regulatory changes revoking or limiting the exemptions to the PUHCA, then the Company may be subject to significant accounting, record-keeping, access to books and records and reporting requirements and failure to comply with such requirements could result in the imposition of penalties and additional compliance obligations.

Substantially all of the Company's generation assets are also subject to the reliability standards promulgated by the designated Electric Reliability Organization (currently the North American Electric Reliability Corporation, or NERC) and approved by FERC. If the Company fails to comply with the mandatory reliability standards, it could be subject to sanctions, including substantial monetary penalties and increased compliance obligations. The Company will also be affected by legislative and regulatory changes, as well as changes to market design, market rules, tariffs, cost allocations and bidding rules that occur in the existing regional markets operated by RTOs or ISOs, such as PJM. The RTOs/ISOs that oversee most of the wholesale power markets impose, and in the future may continue to impose, mitigation, including price limitations, offer caps, non-performance penalties and other mechanisms to address some of the volatility and the potential exercise of market power in these markets. These types of price limitations and other regulatory mechanisms may have a material adverse effect on the profitability of the Company's generation facilities acquired in the future that sell energy, capacity and ancillary products into the wholesale power markets. The regulatory environment for electric generation has undergone significant changes in the last several years due to state and federal policies affecting wholesale competition and the creation of incentives for the addition of large amounts of new renewable generation and, in some cases, transmission assets. These changes are ongoing and the Company cannot predict the future design of the wholesale power markets or the ultimate effect that the changing regulatory environment will have on the Company's business. In addition, in some of these markets, interested parties have proposed to re-regulate the markets or require divestiture of electric generation assets by asset owners or operators to reduce their market share. Other proposals to re-regulate may be made and legislative or other attention to the electric power market restructuring process may delay or reverse the deregulation process. If competitive restructuring of the electric power markets is reversed, discontinued, or delayed, the Company's business prospects and financial results could be negatively impacted.

The Company is subject to environmental laws and regulations that impose extensive and increasingly stringent requirements on its operations, as well as potentially substantial liabilities arising out of environmental contamination.

The Company's assets are subject to numerous and significant federal, state and local laws, including statutes, regulations, guidelines, policies, directives and other requirements governing or relating to, among other things: protection of wildlife, including threatened and endangered species; air emissions; discharges into water; water use; the storage, handling, use, transportation and distribution of dangerous goods and hazardous, residual and other regulated materials, such as chemicals; the prevention of releases of hazardous materials into the environment; the prevention, presence and remediation of hazardous materials in soil and groundwater, both on and offsite; land use and zoning matters; and workers' health and safety matters. The Company's facilities could experience incidents, malfunctions and other unplanned events that could result in spills or emissions in excess of permitted levels and result in personal injury, penalties and property damage. As such, the operation of the Company's facilities carries an inherent risk of environmental, health and safety liabilities (including potential civil actions, compliance or remediation orders, fines and other penalties), and may result in the assets being involved from time to time in administrative and judicial proceedings relating to such matters. The Company has implemented environmental, health and safety management programs designed to continually improve environmental, health and safety performance. Environmental laws and regulations have generally become more stringent over time. Significant costs may be incurred for capital expenditures under environmental programs to keep the assets compliant with such environmental laws and regulations. If it is not economical to make those expenditures, it may be necessary to retire or mothball facilities or restrict or modify the Company's operations to comply with more stringent standards. These environmental requirements and liabilities could have a material adverse effect on the business, financial condition, results of operations and cash flows.

Risks that are beyond the Company's control, including but not limited to acts of terrorism or related acts of war, natural disaster, hostile cyber intrusions or other catastrophic events, could have a material adverse effect on the business, financial condition, results of operations and cash flows.

The Company's generation facilities that were acquired or those that the Company otherwise acquires or constructs and the facilities of third parties on which they rely may be targets of terrorist activities, as well as events occurring in response to or in connection with them, that could cause environmental repercussions and/or result in full or partial disruption of the facilities ability to generate, transmit, transport or distribute electricity or natural gas. Strategic targets, such as energy-related facilities, may be at greater risk of future terrorist activities than other domestic targets. Hostile cyber intrusions, including those targeting information systems as well as electronic control systems used at the generating plants and for the related distribution systems, could severely disrupt business operations and result in loss of service to customers, as well as create significant expense to repair security breaches or system damage.

Furthermore, certain of the Company's power generation thermal assets are located in active earthquake zones in California and Arizona, and certain project companies and suppliers conduct their operations in the same region or in other locations that are susceptible to natural disasters. In addition, California and some of the locations where certain suppliers are located, from time to time, have experienced shortages of water, electric power and natural gas. The occurrence of a natural disaster, such as an earthquake, drought, flood or localized extended outages of critical utilities or transportation systems, or any critical resource shortages, affecting the Company or its suppliers, could cause a significant interruption in the business, damage or destroy the Company's facilities or those of its suppliers or the manufacturing equipment or inventory of the Company's suppliers. Any such terrorist acts, environmental repercussions or disruptions or natural disasters could result in a significant decrease in revenues or significant reconstruction or remediation costs, beyond what could be recovered through insurance policies, which could have a material adverse effect on the business, financial condition, results of operations and cash flows.

The operation of the Company’s businesses is subject to cyber-based security and integrity risk.

Numerous functions affecting the efficient operation of the Company’s businesses depend on the secure and reliable storage, processing and communication of electronic data and the use of sophisticated computer hardware and software systems. The operation of the Company's generating assets rely on cyber-based technologies and, therefore, subject to the risk that such systems could be the target of disruptive actions, particularly through cyber-attack or cyber intrusion, including by computer hackers, foreign governments and cyber terrorists, or otherwise be compromised by unintentional events. As a result, operations could be interrupted, property could be damaged and sensitive customer information could be lost or stolen, causing the Company to incur significant losses of revenues, other substantial liabilities and damages, costs to replace or repair damaged equipment and damage to the Company's reputation. In addition, the Company may experience increased capital and operating costs to implement increased security for its cyber systems and generating assets.

Government regulations providing incentives for renewable generation could change at any time and such changes may negatively impact the Company's growth strategy.

The Company's growth strategy depends in part on government policies that support renewable generation and enhance the economic viability of owning renewable electric generation assets. Renewable generation assets currently benefit from various federal, state and local governmental incentives such as ITCs, cash grants in lieu of ITCs, loan guarantees, RPS, programs, modified accelerated cost-recovery system of depreciation and bonus depreciation. In December 2015, the U.S. Congress enacted an extension of the 30% solar ITC so that projects that began construction in 2016 through 2019 will continue to qualify for the 30% ITC. Projects beginning construction in 2020 and 2021 will be eligible for the ITC at the rates of 26% and 22%, respectively. The same legislation also extended the 10-year wind PTC for wind projects that began construction in years 2016 through 2019. Wind projects that begin construction in the years 2018 and 2019 are eligible for PTC at 60% and 40% of the statutory rate per kWh, respectively.

Many states have adopted RPS programs mandating that a specified percentage of electricity sales come from eligible sources of renewable energy. However, the regulations that govern the RPS programs, including pricing incentives for renewable energy, or reasonableness guidelines for pricing that increase valuation compared to conventional power (such as a projected value for carbon reduction or consideration of avoided integration costs), may change. If the RPS requirements are reduced or eliminated, it could lead to fewer future power contracts or lead to lower prices for the sale of power in future power contracts, which could have a material adverse effect on the Company's future growth prospects. Such material adverse effects may result from decreased revenues, reduced economic returns on certain project company investments, increased financing costs, and/or difficulty obtaining financing. Furthermore, the ARRA included incentives to encourage investment in the renewable energy sector, such as cash grants in lieu of ITCs, bonus depreciation and expansion of the U.S. DOE loan guarantee program. It is uncertain what loan guarantees may be made by the U.S. DOE loan guarantee program in the future. In addition, the cash grant in lieu of ITCs program only applies to facilities that commenced construction prior to December 31, 2011, which commencement date may be determined in accordance with the safe harbor if more than 5% of the total cost of the eligible property was paid or incurred by December 31, 2011.

If the Company is unable to utilize various federal, state and local government incentives to acquire additional renewable assets in the future, or the terms of such incentives are revised in a manner that is less favorable to the Company, it may suffer a material adverse effect on the business, financial condition, results of operations and cash flows.

The Company relies on electric interconnection and transmission facilities that it does not own or control and that are subject to transmission constraints within a number of the Company's regions. If these facilities fail to provide the Company with adequate transmission capacity, it may be restricted in its ability to deliver electric power to its customers and may either incur additional costs or forego revenues.

The Company depends on electric interconnection and transmission facilities owned and operated by others to deliver the wholesale power it will sell from its electric generation assets to its customers. A failure or delay in the operation or development of these interconnection or transmission facilities or a significant increase in the cost of the development of such facilities could result in lost revenues. Such failures or delays could limit the amount of power the Company's operating facilities deliver or delay the completion of the Company's construction projects. Additionally, such failures, delays or increased costs could have a material adverse effect on the business, financial condition and results of operations. If a region's power transmission infrastructure is inadequate, the Company's recovery of wholesale costs and profits may be limited. If restrictive transmission price regulation is imposed, the transmission companies may not have a sufficient incentive to invest in expansion of transmission infrastructure. The Company also cannot predict whether interconnection and transmission facilities will be expanded in specific markets to accommodate competitive access to those markets. In addition, certain of the Company's operating facilities' generation of electricity may be curtailed without compensation due to transmission limitations or limitations on the electricity grid's ability to accommodate intermittent electricity generating sources, reducing the Company's revenues and impairing its ability to capitalize fully on a particular facility's generating potential. Such curtailments could have a material adverse effect on the business, financial condition, results of operations and cash flows. Furthermore, economic congestion on transmission networks in certain of the markets in which the Company operates may occur and the Company may be deemed responsible for congestion costs. If the Company were liable for such congestion costs, its financial results could be adversely affected.

The Company's costs, results of operations, financial condition and cash flows could be adversely impacted by the disruption of the fuel supplies necessary to generate power at its conventional and thermal power generation facilities.

Delivery of fossil fuels to fuel the Company's conventional and thermal generation facilities is dependent upon the infrastructure (including natural gas pipelines) available to serve each such generation facility as well as upon the continuing financial viability of contractual counterparties. As a result, the Company is subject to the risks of disruptions or curtailments in the production of power at these generation facilities if a counterparty fails to perform or if there is a disruption in the fuel delivery infrastructure.

If the Company is deemed to be an investment company, the Company may be required to institute burdensome compliance requirements and the Company's activities may be restricted, which may make it difficult for the Company to complete strategic acquisitions or effect combinations.

If the Company is deemed to be an investment company under the Investment Company Act of 1940, or the Investment Company Act, the Company's business would be subject to applicable restrictions under the Investment Company Act, which could make it impracticable for the Company to continue its business as contemplated.

The Company believes it is not an investment company under Section 3(b)(1) of the Investment Company Act because the Company is primarily engaged in a non-investment company business. The Company intends to conduct its operations so that the Company will not be deemed an investment company. However, if the Company were to be deemed an investment company, restrictions imposed by the Investment Company Act, including limitations on the Company's capital structure and the Company's ability to transact with affiliates, could make it impractical for the Company to continue its business as contemplated.

The Company depends on key management employees, the loss of any of which could have a material adverse effect on the Company's financial condition and results of operations.

The Company believes its current operations and future success depend largely on the continued services of the management employees that it employs, in particular Christopher Sotos, the Company’s President and Chief Executive Officer and Chad Plotkin, the Company’s Senior Vice President and Chief Financial Officer. Although the Company currently has access to the resources of NRG, the loss of Mr. Sotos’ or Mr. Plotkin’s services, or other key management personnel employed by the Company in connection with the NRG Transaction or in the future, could have a material adverse effect on the Company’s financial condition and results of operations.

Risks Related to the Company's Relationship with NRG

NRG exercises substantial influence over the Company through its position as controlling shareholder of Yield, Inc. The Company is highly dependent on NRG.

NRG owns all of the outstanding Class B and Class D common stock of Yield, Inc. and owns 55.1% of the combined voting power of Yield, Inc. as of December 31, 2017. As a result of NRG's ownership of Yield, Inc. and Yield, Inc.'s position as sole managing member of the Company, NRG has a substantial influence on the Company's affairs and its voting power will constitute a large percentage of any quorum of Yield, Inc.'s stockholders voting on any matter requiring the approval of its stockholders. Such matters include approval of mergers or sale of all or substantially all of its assets. This concentration of ownership may also have the effect of delaying or preventing a change in control of Yield, Inc. or discouraging others from making tender offers for their shares. In addition, NRG has the right to elect all of Yield, Inc.'s directors. NRG may cause corporate actions to be taken even if their interests conflict with the interests of Yield, Inc.'s other stockholders (including holders of Yield, Inc.'s Class A and Class C common stock). If the NRG Transaction is consummated, GIP will become Yield, Inc.'s controlling stockholder and, like NRG, will have substantial control and influence over the Company. See the risk factor entitled “Following the consummation of the NRG Transaction, GIP and its affiliates will control the Company and have the ability to designate a majority of the members of the Company’s Board.”

Furthermore, the Company depends on the management and administration services provided by or under the direction of NRG under the Management Services Agreement. NRG personnel and support staff that provide services to the Company under the Management Services Agreement are not required to, and the Company does not expect that they will, have as their primary responsibility the management and administration of the Company or to act exclusively for the Company and the Management Services Agreement does not require any specific individuals to be provided by NRG. Under the Management Services Agreement, NRG has the discretion to determine which of its employees perform assignments required to be provided to the Company. Any failure to effectively manage the Company's operations or to implement its strategy could have a material adverse effect on the business, financial condition, results of operations and cash flows. The Management Services Agreement will continue in perpetuity, until terminated in accordance with its terms.

The Company also depends upon NRG for the provision of management, administration and certain other services at all of the Company's facilities and contracts with NRG, or its subsidiaries, to procure fuel and sell power for certain of its operating facilities. Any failure by NRG to perform its requirements under these arrangements or the failure by the Company to identify and contract with replacement service providers, if required, could adversely affect the operation of the Company's facilities and have a material adverse effect on the business, financial condition, results of operations and cash flows.

In connection with the proposed NRG Transaction, GIP has agreed to enter into certain agreements with the Company relating to the provision of services and NRG has agreed to enter into certain agreements with the Company relating to transition services and ongoing commercial arrangements. While the provision of transitional services is contemplated under the proposed NRG Transaction, it is uncertain whether, after the transition services end, GIP or its affiliates would continue to provide the same services, or offer the same capabilities and resources, to the Company that the Company currently receives from NRG or whether the Company may have to seek alternative service providers. The Company may not be able to replicate the same level of services, capabilities, experience and familiarity with the Company’s business offered by NRG either through GIP or through alternative service providers or on terms or costs similar to those provided by NRG. The loss of services provided by NRG and the benefits offered to the Company through its relationship with NRG, such as management, operational and financing expertise, could have an impact on the Company’s business, financial condition, results of operations and cash flows. See also the risk factor entitled “If NRG terminates the Management Services Agreement or defaults in the performance of its obligations under the agreement, or if the transition services to be provided by NRG to the Company in connection with the consummation of the NRG Transaction are inadequate or end, the Company may be unable to contract with a substitute service provider on similar terms, or at all.”

The Company may not be able to consummate future acquisitions from NRG.

Until the NRG Transaction is consummated, if at all, the Company's ability to grow through acquisitions depends, in part, on NRG's ability to identify and present the Company with acquisition opportunities. NRG established the Company to hold and acquire a diversified suite of power generating assets in the U.S. and its territories. Although NRG has agreed to grant the Company a right of first offer with respect to certain power generation assets that NRG may elect to sell in the future, NRG is under no obligation to sell any such power generation assets or to accept any related offer from the Company. In addition, NRG has not agreed to commit any minimum level of dedicated resources for the pursuit of renewable power-related acquisitions. There are a number of factors which could materially and adversely impact the extent to which suitable acquisition opportunities are made available from NRG, including:

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the same professionals within NRG's organization that are involved in acquisitions that are suitable for the Company have responsibilities within NRG's broader asset management business, which may include sourcing acquisition opportunities for NRG. Limits on the availability of such individuals will likewise result in a limitation on the availability of acquisition opportunities for the Company; and

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in addition to structural limitations, the question of whether a particular asset is suitable is highly subjective and is dependent on a number of factors including an assessment by NRG relating to the Company's liquidity position at the time, the risk profile of the opportunity and its fit with the balance of the Company's then current operations and other factors. If NRG determines that an opportunity is not suitable for the Company, it may still pursue such opportunity on its own behalf, or on behalf of another NRG affiliate.

In making these determinations, NRG may be influenced by factors that result in a misalignment with the Company's interests or conflict of interest.

The departure of some or all of NRG's employees could prevent the Company from achieving its objectives.

The Company depends on the diligence, skill and business contacts of NRG's professionals and the information and opportunities they generate during the normal course of their activities. Furthermore, approximately 24% of NRG's employees at the Company's generation plants are covered by collective bargaining agreements as of December 31, 2017. The Company's future success will depend on the continued service of these individuals, who are not obligated to remain employed with NRG, or otherwise successfully renegotiate their collective bargaining agreements when such agreements expire or otherwise terminate. NRG has experienced departures of key professionals and personnel in the past and may do so if the NRG Transaction is consummated, and the Company cannot predict the impact that any such departures will have on its ability to achieve its objectives. The Management Services Agreement does not require NRG to maintain the employment of any of its professionals or to cause any particular professional to provide services to the Company or on its behalf. The departure of a significant number of NRG's professionals or a material portion of the NRG employees who work at any of the Company's facilities for any reason, or the failure to appoint qualified or effective successors in the event of such departures, could have a material adverse effect on the Company's ability to achieve its objectives.

The Company's organizational and ownership structure may create significant conflicts of interest that may be resolved in a manner that is not in the best interests of the Company and that may have a material adverse effect on the business, financial condition, results of operations and cash flows.

The Company's organizational and ownership structure involves a number of relationships that may give rise to certain conflicts of interest between the Company and NRG. Pursuant to the Management Services Agreement with NRG, certain of the Company's executive officers are shared NRG executives and devote their time to both the Company and NRG as needed to conduct the respective businesses. Although the Company's directors and executive officers owe fiduciary duties to the Company's stockholders, these shared NRG executives have fiduciary and other duties to NRG, which duties may be inconsistent with the Company's best interests. In addition, NRG and its representatives, agents and affiliates have access to the Company's confidential information. Although some of these persons are subject to confidentiality obligations pursuant to confidentiality agreements or implied duties of confidence, the Management Services Agreement does not contain general confidentiality provisions.

Additionally, all of the Company's executive officers continue to have economic interests in NRG and, accordingly, the benefit to NRG from a transaction between the Company and NRG will proportionately inure to their benefit as holders of economic interests in NRG. NRG is a related person under the applicable securities laws governing related person transactions and may have interests which differ from the Company's interests, including with respect to the types of acquisitions made, the timing and amount of distributions by the Company, the reinvestment of returns generated by the Company's operations, the use of leverage when making acquisitions and the appointment of outside advisors and service providers. Any material transaction between the Company and NRG will be subject to Yield, Inc.'s related person transaction policy, which will require prior approval of such transaction by Yield, Inc.'s Corporate Governance, Conflicts and Nominating Committee. Those of the Company's executive officers who have economic interests in NRG may be conflicted when advising Yield, Inc.'s Corporate Governance, Conflicts and Nominating Committees or otherwise participating in the negotiation or approval of such transactions. These executive officers have significant project- and industry-specific expertise that could prove beneficial to the Company's decision-making process and the absence of such strategic guidance could have a material adverse effect on the board committees' ability to evaluate any such transaction. Furthermore, the creation of Yield, Inc.'s Corporate Governance, Conflicts and Nominating Committee and Yield, Inc.'s related person transaction approval policy may not insulate the Company from derivative claims with respect to related person transactions and the conflicts of interest described in this risk factor. Regardless of the merits of such claims, the Company may be required to expend significant management time and financial resources in the defense thereof. Additionally, to the extent the Company fails to appropriately deal with any such conflicts, it could negatively impact the Company's reputation and ability to raise additional funds and the willingness of counterparties to do business with the Company, all of which could have a material adverse effect on the business, financial condition, results of operations and cash flows.

The Company may be unable or unwilling to terminate the Management Services Agreement.

The Management Services Agreement provides that the Company may terminate the agreement upon 30 days prior written notice to NRG upon the occurrence of any of the following: (i) NRG defaults in the performance or observance of any material term, condition or covenant contained therein in a manner that results in material harm to the Company and the default continues unremedied for a period of 30 days after written notice thereof is given to NRG; (ii) NRG engages in any act of fraud, misappropriation of funds or embezzlement that results in material harm to the Company; (iii) NRG is grossly negligent in the performance of its duties under the agreement and such negligence results in material harm to the Company; or (iv) upon the happening of certain events relating to the bankruptcy or insolvency of NRG. Furthermore, if the Company requests an amendment to the scope of services provided by NRG under the Management Services Agreement and is not able to agree with NRG as to a change to the service fee resulting from a change in the scope of services within 180 days of the request, the Company will be able to terminate the agreement upon 30 days prior notice to NRG. The Company will not be able to terminate the agreement for any other reason, including if NRG experiences a change of control, and the agreement continues in perpetuity, until terminated in accordance with its terms.

If NRG terminates the Management Services Agreement or defaults in the performance of its obligations under the agreement, or if the transition services to be provided by NRG to the Company in connection with the consummation of the NRG Transaction are inadequate or end, the Company may be unable to contract with a substitute service provider on similar terms, or at all.

The Company relies on NRG to provide management services under the Management Services Agreement and has limited executive or senior management personnel independent from NRG. The Management Services Agreement provides that NRG may terminate the agreement upon 180 days prior written notice of termination to the Company if it defaults in the performance or observance of any material term, condition or covenant contained in the agreement in a manner that results in material harm and the default continues unremedied for a period of 30 days after written notice of the breach is given. If NRG terminates the Management Services Agreement or defaults in the performance of its obligations under the agreement, or if the transition services to be provided by NRG to the Company, in the event the NRG Transaction is consummated, are not adequate or end, the Company may be unable to contract with GIP or a substitute service provider on similar terms or at all, and the costs of substituting service providers may be substantial. In addition, in light of NRG's familiarity with the Company's assets, GIP or a substitute service provider may not be able to provide the same level of service due to lack of pre-existing synergies. If the Company cannot locate a service provider that is able to provide substantially similar services as NRG does under the Management Services Agreement on similar terms, it could have a material adverse effect on the business, financial condition, results of operation and cash flows.

The liability of NRG is limited under the Company's arrangements with it and the Company has agreed to indemnify NRG against claims that it may face in connection with such arrangements, which may lead NRG to assume greater risks when making decisions relating to the Company than it otherwise might if acting solely for its own account.

Under the Management Services Agreement, NRG does not assume any responsibility other than to provide or arrange for the provision of the services described in the Management Services Agreement in good faith. In addition, under the Management Services Agreement, the liability of NRG and its affiliates is limited to the fullest extent permitted by law to conduct involving bad faith, fraud, willful misconduct or gross negligence or, in the case of a criminal matter, action that was known to have been unlawful. In addition, the Company has agreed to indemnify NRG to the fullest extent permitted by law from and against any claims, liabilities, losses, damages, costs or expenses incurred by an indemnified person or threatened in connection with the Company's operations, investments and activities or in respect of or arising from the Management Services Agreement or the services provided by NRG, except to the extent that the claims, liabilities, losses, damages, costs or expenses are determined to have resulted from the conduct in respect of which such persons have liability as described above. These protections may result in NRG tolerating greater risks when making decisions than otherwise might be the case, including when determining whether to use leverage in connection with acquisitions. The indemnification arrangements to which NRG is a party may also give rise to legal claims for indemnification that are adverse to the Company.

Certain of the Company’s PPAs and project-level financing arrangements include provisions that would permit the counterparty to terminate the contract or accelerate maturity in the event NRG ceases to control or own, directly or indirectly, a majority of the voting power of the Company.

Certain of the Company’s PPAs and project-level financing arrangements contain change in control provisions that provide the counterparty with a termination right or the ability to accelerate maturity in the event of a change of control of the Company without the counterparty's consent. These provisions are triggered in the event NRG ceases to own, directly or indirectly, capital stock representing more than 50% of the voting power of all of Yield, Inc.’s capital stock outstanding on such date, or, in some cases, if NRG ceases to be the majority owner, directly or indirectly, of the applicable project subsidiary. As a result, if NRG ceases to control, or in some cases, own a majority of the voting power of the Company, as is contemplated by the NRG Transaction, the counterparties could terminate such contracts or accelerate the maturity of such financing arrangements. Even though the Company’s consent to the NRG Transaction is conditioned upon the receipt of consents from such counterparties, the Company may have to expend significant resources and funds to obtain the consents of such counterparties to the NRG Transaction and there can be no assurance that such counterparties will provide their consents at all. The termination of any of the Company’s PPAs or the acceleration of the maturity of any of the Company’s project-level financing could have a material adverse effect on the Company’s business, financial condition, results of operations and cash flow.

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Annual Report on Form 10-K of NRG Yield LLC, 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 and the following:


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


•	Potential risks to the Company as a result of the NRG Transaction;


•	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;


•	Changes in law, including judicial decisions;

•

Hazards customary to the power production industry and power generation operations such as fuel and electricity price volatility, unusual weather conditions (including wind and solar 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 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 amended and restated revolving credit facility and in the indentures governing the Senior Notes;


•	Cyber terrorism and inadequate cybersecurity, or the occurrence of a catastrophic loss and the possibility that the Company may not have adequate insurance to cover losses resulting from such hazards or the inability of the Company's insurers to provide coverage;


•	The Company's ability to engage in successful mergers and acquisitions activity; 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 Annual Report on Form 10-K should not be construed as exhaustive.

Item 1B — Unresolved Staff Comments

None.

Item 2 — Properties

Listed below are descriptions of the Company's interests in facilities, operations and/or projects owned or leased as of December 31, 2017.



		Capacity
		Rated MW	Net MW^(a)	Owner-ship				PPA Terms
Assets	Location	Rated MW	Net MW^(a)	Owner-ship		Fuel	COD	Counterparty	Expiration
Conventional
El Segundo	El Segundo, CA	550	550	100	%	Natural Gas	August 2013	Southern California Edison	2023
GenConn Devon	Milford, CT	190	95	50	%	Natural Gas/Oil	June 2010	Connecticut Light & Power	2040
GenConn Middletown	Middletown, CT	190	95	50	%	Natural Gas/Oil	June 2011	Connecticut Light & Power	2041
Marsh Landing	Antioch, CA	720	720	100	%	Natural Gas	May 2013	Pacific Gas and Electric	2023
Walnut Creek	City of Industry, CA	485	485	100	%	Natural Gas	May 2013	Southern California Edison	2023
Total Conventional		2,135	1,945
Utility Scale Solar
Agua Caliente	Dateland, AZ	290	46	16	%	Solar	June 2014	Pacific Gas and Electric	2039
Alpine	Lancaster, CA	66	66	100	%	Solar	January 2013	Pacific Gas and Electric	2033
Avenal	Avenal, CA	45	23	50	%	Solar	August 2011	Pacific Gas and Electric	2031
Avra Valley	Pima County, AZ	26	26	100	%	Solar	December 2012	Tucson Electric Power	2032
Blythe	Blythe, CA	21	21	100	%	Solar	December 2009	Southern California Edison	2029
Borrego	Borrego Springs, CA	26	26	100	%	Solar	February 2013	San Diego Gas and Electric	2038
CVSR	San Luis Obispo, CA	250	250	100	%	Solar	October 2013	Pacific Gas and Electric	2038
Desert Sunlight 250	Desert Center, California	250	63	25	%	Solar	December 2014	Southern California Edison	2034
Desert Sunlight 300	Desert Center, California	300	75	25	%	Solar	December 2014	Pacific Gas and Electric	2039
Four Brothers Solar	New Castle/Milford, UT	320	160	50	%	Solar	July 2016 - August 2016	PacifiCorp	2036
Granite Mountain	Cedar City, UT	130	65	50	%	Solar	September 2016	PacifiCorp	2036
Iron Springs	Cedar City, UT	80	40	50	%	Solar	August 2016	PacifiCorp	2036
Kansas South	Lemoore, CA	20	20	100	%	Solar	June 2013	Pacific Gas and Electric	2033
Roadrunner	Santa Teresa, NM	20	20	100	%	Solar	August 2011	El Paso Electric	2031
TA High Desert	Lancaster, CA	20	20	100	%	Solar	March 2013	Southern California Edison	2033
Total Utility Scale Solar		1,864	921
Distributed Solar
Apple I LLC Projects	CA	9	9	100	%	Solar	October 2012 - December 2012	Various	2032
AZ DG Solar Projects	AZ	5	5	100	%	Solar	December 2010 - January 2013	Various	2025-2033
SPP Projects	Various	25	25	100	%	Solar	June 2008 - June 2012	Various	2026-2037
Other DG Projects	Various	13	13	100	%	Solar	October 2012 - October 2015	Various	2023-2039
Total Distributed Solar		52	52
Wind
Alta I	Tehachapi, CA	150	150	100	%	Wind	December 2010	Southern California Edison	2035



		Capacity
		Rated MW	Net MW^(a)	Owner-ship				PPA Terms
Assets	Location	Rated MW	Net MW^(a)	Owner-ship		Fuel	COD	Counterparty	Expiration
Alta II	Tehachapi, CA	150	150	100	%	Wind	December 2010	Southern California Edison	2035
Alta III	Tehachapi, CA	150	150	100	%	Wind	February 2011	Southern California Edison	2035
Alta IV	Tehachapi, CA	102	102	100	%	Wind	March 2011	Southern California Edison	2035
Alta V	Tehachapi, CA	168	168	100	%	Wind	April 2011	Southern California Edison	2035
Alta X^(b)	Tehachapi, CA	137	137	100	%	Wind	February 2014	Southern California Edison	2038
Alta XI^(b)	Tehachapi, CA	90	90	100	%	Wind	February 2014	Southern California Edison	2038
Buffalo Bear	Buffalo, OK	19	19	100	%	Wind	December 2008	Western Farmers Electric Co-operative	2033
Crosswinds ^(b)	Ayrshire, IA	21	21	99	%	Wind	June 2007	Corn Belt Power Cooperative	2027
Elbow Creek ^(b)	Howard County, TX	122	122	100	%	Wind	December 2008	NRG Power Marketing LLC	2022
Elkhorn Ridge ^(b)	Bloomfield, NE	81	54	66.7	%	Wind	March 2009	Nebraska Public Power District	2029
Forward ^(b)	Berlin, PA	29	29	100	%	Wind	April 2008	Constellation NewEnergy, Inc.	2022
Goat Wind ^(b)	Sterling City, TX	150	150	100	%	Wind	April 2008/June 2009	Dow Pipeline Company	2025
Hardin ^(b)	Jefferson, IA	15	15	99	%	Wind	May 2007	Interstate Power and Light Company	2027
Laredo Ridge	Petersburg, NE	80	80	100	%	Wind	February 2011	Nebraska Public Power District	2031
Lookout ^(b)	Berlin, PA	38	38	100	%	Wind	October 2008	Southern Maryland Electric Cooperative	2030
Odin ^(b)	Odin, MN	20	20	99.9	%	Wind	June 2008	Missouri River Energy Services	2028
Pinnacle	Keyser, WV	55	55	100	%	Wind	December 2011	Maryland Department of General Services and University System of Maryland	2031
San Juan Mesa ^(b)	Elida, NM	120	90	75	%	Wind	December 2005	Southwestern Public Service Company	2025
Sleeping Bear ^(b)	Woodward, OK	95	95	100	%	Wind	October 2007	Public Service Company of Oklahoma	2032
South Trent	Sweetwater, TX	101	101	100	%	Wind	January 2009	AEP Energy Partners	2029
Spanish Fork ^(b)	Spanish Fork, UT	19	19	100	%	Wind	July 2008	PacifiCorp	2028
Spring Canyon II ^(b)	Logan County, CO	32	29	90.1	%	Wind	October 2014	Platte River Power Authority	2039
Spring Canyon III^(b)	Logan County, CO	28	25	90.1	%	Wind	December 2014	Platte River Power Authority	2039
Taloga	Putnam, OK	130	130	100	%	Wind	July 2011	Oklahoma Gas & Electric	2031
Wildorado ^(b)	Vega, TX	161	161	100	%	Wind	April 2007	Southwestern Public Service Company	2027
Total Wind		2,263	2,200
Thermal Generation
Dover	Dover, DE	103	103	100	%	Natural Gas	June 2013	NRG Power Marketing LLC	2018
Paxton Creek Cogen	Harrisburg, PA	12	12	100	%	Natural Gas	November 1986	Power sold into PJM markets
Princeton Hospital	Princeton, NJ	5	5	100	%	Natural Gas	January 2012	Excess power sold to local utility
Tucson Convention Center	Tucson, AZ	2	2	100	%	Natural Gas	January 2003	Excess power sold to local utility

Capacity

Rated MW

Net MW^(a)

Owner-ship

PPA Terms

Assets

Location

Fuel

COD

Counterparty

Expiration

University of Bridgeport

Bridgeport, CT

100

Natural Gas

April 2015

University of Bridgeport

2034

Total Thermal Generation

123

Total NRG Yield, Inc. ^(c)

6,437

5,241

^(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 December 31, 2017.

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

^(c) NRG Yield's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. NRG Yield's generation capacity including this noncontrolling interest was 5,247 MWs.

In addition to the facilities owned or leased in the table above, the Company entered into partnerships to own or purchase solar power generation projects, as well as other ancillary related assets from a related party via intermediate funds. The Company does not consolidate these partnerships and accounts for them as equity method investments. The Company's net interest in these projects is 247 MW based on cash to be distributed. For further discussions, refer to Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities to the Consolidated Financial Statements.

The following table summarizes the Company's thermal steam and chilled water facilities as of December 31, 2017:



Name and Location of Facility	Thermal Energy Purchaser	% Owned	Rated Megawatt Thermal Equivalent Capacity (MWt)	Net Megawatt Thermal Equivalent Capacity (MWt)	Generating Capacity
NRG Energy Center Minneapolis, MN	Approx. 100 steam and 55 chilled water customers	100	322 136	322 136	Steam: 1,100 MMBtu/hr. Chilled water: 38,700 tons
NRG Energy Center San Francisco, CA	Approx. 180 steam customers	100	133	133	Steam: 454 MMBtu/hr.
NRG Energy Center Omaha, NE	Approx. 60 steam and 65 chilled water customers	100 12^(a)100 0^(a)	142 73 77 26	142 9 77 0	Steam: 485 MMBtu/hr Steam: 250 MMBtu/hr Chilled water: 22,000 tons Chilled water: 7,250 tons
NRG Energy Center Harrisburg, PA	Approx. 125 steam and 5 chilled water customers	100	108 13	108 13	Steam: 370 MMBtu/hr. Chilled water: 3,600 tons
NRG Energy Center Phoenix, AZ	Approx. 35 chilled water customers	24^(a) 100 12^(a) 0^(a)	5 104 14 28	1 104 2 0	Steam: 17 MMBtu/hr Chilled water: 29,600 tons Chilled water: 3,920 tons Chilled water: 8,000 tons
NRG Energy Center Pittsburgh, PA	Approx. 25 steam and 25 chilled water customers	100	88 49	88 49	Steam: 302 MMBtu/hr. Chilled water: 13,874 tons
NRG Energy Center San Diego, CA	Approx. 20 chilled water customers	100	31	31	Chilled water: 8,825 tons
NRG Energy Center Dover, DE	Kraft Heinz Company; Proctor and Gamble	100	66	66	Steam: 225 MMBtu/hr.
NRG Energy Center Princeton, NJ	Princeton HealthCare System	100	21 17	21 17	Steam: 72 MMBtu/hr. Chilled water: 4,700 tons
	Total Generating Capacity (MWt)		1,453	1,319

^(a) Net MWt capacity 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.

Other Properties

Through the Management Services Agreement with NRG, the Company utilizes NRG's leased corporate headquarters offices at 804 Carnegie Center, Princeton, New Jersey.

Item 3 — Legal Proceedings

See Item 15 — Note 14, Commitments and Contingencies, to the Consolidated Financial Statements for discussion of the material legal proceedings to which the Company is a party.

Item 4 — Mine Safety Disclosures

Not applicable.

PART II

Item 5 — Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Market Information and Holders

As of the date of this report, there is no publicly-traded market for the Company's membership units. All of the Company's Class A and Class C units are held by Yield, Inc. and all of the Company's Class B and Class D units are held by NRG.

Distributions

The following table lists the distributions paid on the Company's Class A, Class B, Class C and Class D units during the year ended December 31, 2017:



	Fourth Quarter 2017		Third Quarter 2017		Second Quarter 2017		First Quarter 2016
Distributions per Class A and Class B unit	$	0.288	$	0.28	$	0.27	$	0.260
Distributions per Class C and Class D unit	$	0.288	$	0.28	$	0.27	$	0.260

On February 15, 2018, the Company declared a quarterly distribution on its Class A, Class B, Class C and Class D units of $0.298 per unit payable on March 15, 2018.

Item 6 — Selected Financial Data

The following table presents the Company's historical selected financial data, which has been recast to include the Drop Down Assets, as if the transfers had taken place from the beginning of the financial statements period, or from the date the respective entities were under common control (if later than the beginning of the financial statements period). The acquisitions are further described in Item 15 — Note 3, Business Acquisitions, to the Consolidated Financial Statements. Additionally, for all periods prior to the formation of the Company, the data below reflects the Company's accounting predecessor, or NRG Yield, the financial statements of which were prepared on a ''carve-out'' basis from NRG and are intended to represent the financial results of the contracted renewable energy and conventional generation and thermal infrastructure assets in the U.S. that were acquired by the Company on July 22, 2013. For all periods subsequent to the formation of the Company, the data below reflects the Company's consolidated financial results.

This historical data should be read in conjunction with the Consolidated Financial Statements and the related notes thereto in Item 15 and Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.



	Fiscal year ended December 31,
(In millions)	2017			2016			2015			2014			2013
Statement of Income Data:
Operating Revenues
Total operating revenues	$	1,009		$	1,035		$	968		$	844		$	451
Operating Costs and Expenses
Cost of operations	326			308			323			279			156
Depreciation and amortization	334			303			303			240			98
Impairment losses	44			185			1			—			—
General and administrative	19			14			10			8			7
Acquisition-related transaction and integration costs	3			1			3			4			—
Total operating costs and expenses	726			811			640			531			261
Operating Income	283			224			328			313			190
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	71			60			31			22			27
Other income, net	4			3			3			6			4
Loss on debt extinguishment	(3		)	—			(9		)	(1		)	—
Interest expense	(293		)	(272		)	(258		)	(217		)	(72		)
Total other expense, net	(221		)	(209		)	(233		)	(190		)	(41		)
Income Before Income Taxes	62			15			95			123			149
Income tax expense (benefit)	—			—			—			—			(3		)
Net Income	62			15			95			$	123		$	152
Less: Net (loss) income attributable to noncontrolling interests	(75		)	(111		)	(62		)	9			—
Net Income Attributable to NRG Yield LLC	$	137		$	126		$	157		$	114		$	152

Other Financial Data:
Capital expenditures	$	31		$	20		$	29		$	79		$	790
Cash Flow Data:
Net cash provided by (used in):
Operating activities	$	516		$	577		$	424		$	363		$	174
Investing activities	(283		)	(131		)	(1,098		)	(760		)	(987		)
Financing activities	(416		)	(202		)	354			767			853
Balance Sheet Data (at period end):
Cash and cash equivalents	$	146		$	321		$	110		$	430		$	60
Property, plant and equipment, net	5,204			5,554			5,980			6,119			3,488
Total assets	8,154			8,746			8,759			8,930			4,831
Long-term debt, including current maturities	5,845			6,069			5,692			5,828			2,916
Total liabilities	6,146			6,382			6,054			6,173			3,221
Total members' equity	2,008			2,364			2,705			2,757			1,610

Item 7 — 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 Drop Down Assets acquired from NRG. As further discussed in Item 15 — Note 1, Nature of Business, to the Consolidated Financial Statements, the purchases of these assets were accounted for in accordance with ASC 805-50, Business Combinations - Related Issues, whereas 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/from NRG and offset to the noncontrolling interest on the Company's consolidated balance sheet. In accordance with GAAP, 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).

As you read this discussion and analysis, refer to the Company's Consolidated Statements of Operations to this Form 10-K, which present the results of operations for the years ended December 31, 2017, 2016 and 2015. Also refer to Item 1 — Business and Item 1A — Risk Factors, which include 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 that has historically served 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 distribution 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 5,118 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 15 years as of December 31, 2017, based on CAFD. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,319 net MWt and electric generation capacity of 123 net MW. These thermal infrastructure assets provide steam, hot 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.

Strategic Sponsorship with Global Infrastructure Partners

Enhanced ROFO pipeline — Upon closing, the Company will enter into a new ROFO agreement with GIP that immediately adds 550 MW to the current pipeline. The NRG ROFO Agreement will be amended to remove the Ivanpah solar facility.

Voting and Governance Agreement — As part of the NRG Transaction, the parties have agreed to enter into a voting and governance agreement, which would provide that:


•	the Chief Executive Officer of Yield, Inc. will at all times be a full-time Yield, Inc. employee appointed by the Board of Directors, or the Board, of Yield, Inc.;


•	the parties thereto will use their commercially reasonable efforts to submit to Yield, Inc.’s stockholders at Yield, Inc.'s 2019 Annual Meeting of Stockholders a charter amendment to classify the Board into two classes (with the independent directors and directors designated by an affiliate of GIP allocated across the two classes); and


•	the Board will be expanded to nine members at the closing of the NRG Transaction, comprised at that date of five directors designated by GIP, three independent directors and Yield, Inc.’s Chief Executive Officer.

Significant Events

NRG Transaction


•	On February 6, 2018, NRG entered into agreements with GIP for the sale of 100% of its interest in NRG Yield, Inc. and its renewable energy development and operations platform. In connection with this, the Company entered into a Consent and Indemnity Agreement with NRG and GIP. For further discussion, refer to Item 1 — Business.

Drop Down Assets Acquisitions

On February 6, 2018, the Company entered into an agreement with NRG to purchase its interest in Carlsbad Energy Holdings LLC, which indirectly owns the Carlsbad project, a 527 MW natural gas fired project in Carlsbad, CA. The purchase price for the transaction is $365 million in cash consideration, subject to working capital and other adjustments. The transaction is expected to close in the fourth quarter of 2018 and is contingent upon the consummation of the NRG Transaction.


•	On January 24, 2018, the Company entered into an agreement with NRG to acquire 100% of NRG's ownership interest in Buckthorn Solar for total consideration of $42 million, subject to adjustments, and is expected to close in the first quarter of 2018.


•	As discussed in Item 15 — Note 3, Business Acquisitions, to the Consolidated Financial Statements, the Company acquired the following:

◦

On November 1, 2017, a 38 MW solar portfolio primarily comprised of assets from NRG's Solar Power Partners (SPP) funds and other projects developed by NRG, or the November 2017 Drop Down Assets, for cash consideration of $74 million plus assumed non-recourse debt of $26 million. During the quarter ended September 30, 2017, NRG recorded an impairment of $13 million related to the November 2017 Drop Down Assets.

◦

On August 1, 2017, the remaining 25% interest in NRG Wind TE Holdco, a portfolio of 12 wind projects, from NRG for total cash consideration of $44 million. The purchase agreement also included potential additional payments to NRG dependent upon actual energy prices for merchant periods beginning in 2027, which were estimated and accrued as contingent consideration in the amount of $8 million as of December 31, 2017.


◦	On March 27, 2017, the following entities: Agua Caliente Borrower 2 LLC and NRG's interests in the Utah Solar Portfolio, for cash consideration of $132 million. The Company recorded the acquired interests as equity method investments. The Company also assumed non-recourse debt of $41 million and $287 million on Agua Caliente Borrower 2 LLC and the Utah Solar Portfolio.

Impairment Losses

•

During the fourth quarter of 2017, the Company recorded asset impairment losses of $31 million, with respect to Elbow Creek and Forward projects from the Renewables segment. For further discussion, refer to Management’s discussion of the results of operations for the years ended December 31, 2017 and 2016 and Critical Accounting Policies in this Item 7 below, as well as Item 15 — Note 9, Asset Impairments, to the Consolidated Financial Statements.

Financing Activities

•

On February 6, 2018, NRG Yield Operating LLC and NRG Yield LLC amended the revolving credit facility to modify the change of control provisions to permit the consummation of the NRG Transaction, and also to permit NRG Yield Operating LLC, NRG Yield LLC and certain subsidiaries to incur up to $1.5 billion of unsecured indebtedness in order to repurchase or make other required cash payments, in each case if applicable, with respect to NRG Yield Operating LLC’s outstanding senior notes and NRG Yield's outstanding convertible notes in connection with the NRG Transaction.

•

On March 16, 2017, NRG Energy Center Minneapolis LLC, a subsidiary of the Company, amended the shelf facility of its existing Thermal financing arrangement to allow for the issuance of an additional $10 million of Series F notes at a 4.60% interest rate, or the Series F Notes, increasing the total principal amount of notes available for issuance under the shelf facility to $80 million. The Series F Notes are secured by substantially all of the assets of NRG Energy Center Minneapolis LLC. NRG Thermal LLC has guaranteed the indebtedness and its guarantee is secured by a pledge of the equity interests in all of NRG Thermal LLC’s subsidiaries.


•	During the year ended December 31, 2017, NRG Yield, Inc. issued 1,921,866 shares of Class C common stock under the ATM Program for gross proceeds of $35 million and incurred commission fees of $346 thousand, as described in Sources of Liquidity in this Item 7.

Environmental Matters and Regulatory Matters

Details of environmental matters and regulatory matters are presented in Item 1 — Business, Regulatory Matters and Item 1A— Risk Factors. Details of some of this information relate to costs that may impact the Company's financial results.

Trends Affecting Results of Operations and Future Business Performance

Wind and Solar Resource Availability

The availability of the wind and solar resources affects the financial performance of the wind and solar facilities, which may impact the Company’s overall financial performance. Due to the variable nature of the wind and solar resources, the Company cannot predict the availability of the wind and solar resources and the potential variances from expected performance levels from quarter to quarter. To the extent the wind and solar resources are not available at expected levels, it could have a negative impact on the Company’s financial performance for such periods.

Operational Matters

Walnut Creek Forced Outage

During the first half of 2017, Walnut Creek experienced forced outages due to mechanical failures of turbine parts that caused downstream damage to several of the plant's Units, primarily Unit 1. The repairs necessary to return Unit 1 to service were completed in the second quarter of 2017 and the plant has performed reliably since then. The estimated cost of this outage is approximately $2 million after the recovery of insurance proceeds. Also, during 2017, the Company recorded a loss on disposal of assets of $14 million, in relation to the Unit 1 forced outage. In the third quarter of 2017, the Company, through Walnut Creek, executed an amendment to the contractual service agreement with the original equipment manufacturer to improve long term reliability. The amendment provides for the original equipment manufacturer to perform all required, currently available and future turbine reliability upgrades, and collateral damage reimbursement rights in exchange for an investment of $15 million that would be paid over the next five years, of which $8 million is expected to be paid in 2018.

El Segundo Forced Outage

In January 2017, the El Segundo Energy Center began a forced outage on Units 5 and 6 due to increasing vibrations on successive operations at Unit 5. In consultation with the Company’s operations and maintenance service provider, a subsidiary of NRG, the Company elected to replace the rotor on Unit 5. Both Unit 5 and 6 returned to service on February 24, 2017. In July 2017, the Company executed a warranty settlement agreement with the original equipment manufacturer that reduced total cost from $12 million to $5 million.

Consolidated Results of Operations

2017 compared to 2016

The following table provides selected financial information:



	Year ended December 31,
(In millions)	2017			2016			Change
Operating Revenues
Energy and capacity revenues	$	1,078		$	1,104		$	(26	)
Contract amortization	(69		)	(69		)	—
Total operating revenues	1,009			1,035			(26		)
Operating Costs and Expenses
Cost of fuels	63			61			2
Emissions credit amortization	—			6			(6		)
Operations and maintenance	197			176			21
Other costs of operations	66			65			1
Depreciation and amortization	334			303			31
Impairment losses	44			185			(141		)
General and administrative	19			14			5
Acquisition-related transaction and integration costs	3			1			2
Total operating costs and expenses	726			811			(85		)
Operating Income	283			224			59
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	71			60			11
Other income, net	4			3			1
Loss on debt extinguishment	(3		)	—			(3		)
Interest expense	(293		)	(272		)	(21		)
Total other expense, net	(221		)	(209		)	(12		)
Net Income	62			15			47
Less: Net loss attributable to noncontrolling interests	(75		)	(111		)	36
Net Income Attributable to NRG Yield LLC	$	137		$	126		$	11



	Year ended December 31,
Business metrics:	2017	2016
Renewables MWh generated/sold (in thousands) ^(a)	6,844	7,291
Conventional MWh generated (in thousands) ^(a)(b)	1,809	1,697
Thermal MWt sold (in thousands)	1,926	1,966
Thermal MWh sold (in thousands) ^(c)	35	71

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

^(b)Volumes generated are not sold as the Conventional facilities sell capacity rather than energy.

^(c)MWh sold do not include 72 and 204 MWh generated by NRG Dover, a subsidiary of the Company, under the PPA with NRG Power Marketing during the years ended December 31, 2017 and December 31, 2016, respectively, as further described in Item 15 — Note 13, Related Party Transactions, to the Consolidated Financial Statements.

Management’s discussion of the results of operations for the years ended December 31, 2017 and 2016

Gross Margin

The Company calculates gross margin in order to evaluate operating performance as operating revenues less cost of sales, which includes cost of fuel, contract and emission credit amortization and mark-to-market for economic hedging activities.

Economic Gross Margin

In addition to 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 should be viewed as a supplement to and not a substitute for the Company' presentation of gross margin, which is the most directly comparable GAAP measure. Economic gross margin is not intended to represent gross margin. The Company believes that economic gross margin is useful to investors as it is a key operational measure reviewed by the Company's chief operating decision maker. Economic gross margin is defined as energy and capacity revenue less cost of fuels. Economic gross margin excludes the following components from GAAP gross margin: contract amortization, mark-to-market results, emissions credit amortization and (losses) gains on economic hedging activities. Mark-to-market results consist of unrealized gains and losses on contracts that are not yet settled.

The below tables present the composition of gross margin, as well as the reconciliation to economic gross margin for the years ended December 31, 2017 and 2016:



	Conventional			Renewables			Thermal			Total
(In millions)
Year ended December 31, 2017
Energy and capacity revenues	$	341		$	563		$	174		$	1,078
Cost of fuels	(1		)	—			(62		)	(63		)
Contract amortization	(5		)	(62		)	(2		)	(69		)
Gross margin	335			501			110			946
Contract amortization	5			62			2			69
Economic gross margin	$	340		$	563		$	112		$	1,015

Year ended December 31, 2016
Energy and capacity revenues	$	338		$	594		$	172		$	1,104
Cost of fuels	(1		)	—			(60		)	(61		)
Contract amortization	(5		)	(62		)	(2		)	(69		)
Emissions credit amortization	(6		)	—			—			(6		)
Gross margin	326			532			110			968
Contract amortization	5			62			2			69
Emissions credit amortization	6			—			—			6
Economic gross margin	$	337		$	594		$	112		$	1,043

Gross margin decreased by $22 million and economic gross margin decreased by $28 million during the year ended December 31, 2017, compared to the same period in 2016, primarily due to:



(In millions)
Renewables:
A 7% decrease in volume generated by wind projects, due to lower wind resources at the Alta Wind and NRG Wind TE Holdco projects	$	(31	)
Conventional:
Higher revenues due to 2016 higher priced peak season forced outages, as well as additional start-up revenue from Marsh Landing in 2017	3
Decrease in economic gross margin	$	(28	)
Emissions credit amortization of NOx allowances at Walnut Creek and El Segundo in compliance with amendments to the Regional Clean Air Incentives Market program in 2016	6
Decrease in gross margin	$	(22	)

Operations and Maintenance Expense



	Conventional		Renewables		Thermal		Total
(In millions)
Year ended December 31, 2017	$	52	$	97	$	48	$	197
Year ended December 31, 2016	32		96		48		176

Operations and maintenance expense increased by $21 million during the year ended December 31, 2017, compared to the same period in 2016, due to the forced outages in the Conventional segment. The Company recorded higher operations and maintenance costs in Walnut Creek in connection with the Unit 1 forced outages that took place in April of 2017, including an increase of loss on disposal of assets of $12 million, as well as higher operations and maintenance costs in El Segundo due to the forced outages in Units 5 and Unit 6 that took place in January 2017.

Impairment Losses

The Company recorded impairment losses of $44 million and $185 million for the years ended December 31, 2017 and 2016, respectively.

During the fourth quarter of 2017, as the Company updated its estimated cash flows in connection with the preparation and review of the Company’s annual budget, it was determined that both Elbow Creek and Forward projects were impaired due to the continued declining merchant power prices in the post contract periods. As a result, the Company recorded impairment losses of $26 million and $5 million for the Elbow Creek and Forward projects, respectively.

In addition, in connection with the sale of the November 2017 Drop Down Assets, it was identified that undiscounted cash flows were lower than the book value of certain SPP funds and NRG recorded an impairment expense of $13 million. In accordance with the guidance for transfer of assets under common control, the impairment is reflected in the Company's consolidated statements of operations for the period ended December 31, 2017.

During the fourth quarter of 2016, as the Company updated its estimated cash flows in connection with the preparation and review of the Company's annual budget, it was determined that the cash flows for the Elbow Creek and Goat Wind projects and the Forward project were below the carrying value of the related assets, primarily driven by declining merchant power prices in post-contract periods, and that the assets were considered impaired. The Company recorded impairment losses of $117 million, $60 million and $6 million for Elbow Creek, Goat Wind, and Forward, respectively. The other impairments of $2 million related to the projects that were part of the November 2017 Drop Down Assets. Since the acquisition by the Company of the November 2017 Drop Down Assets related to transfer of assets under common control, these impairments were reflected in the Company's consolidated statements of operations for the period ending December 31, 2016. For further discussion see Item 15 — Note 9, Asset Impairments, to the Consolidated Financial Statements, as well as in Critical Accounting Policies and Estimates in this Item 7.

Equity in Earnings of Unconsolidated Affiliates

Equity in earnings of unconsolidated affiliates increased by $11 million during the year ended December 31, 2017, compared to the same period in 2016, primarily due to higher earnings from the solar partnerships with NRG, as well as acquisition of the Utah Solar Portfolio in November 2016, partially offset by lower earnings from the San Juan Mesa investment.

Interest Expense

Interest expense increased by $21 million during the year ended December 31, 2017, compared to the same period in 2016 due to:



	(In millions)
Assumption of the Utah Solar Portfolio debt in connection with the March 2017 Drop Down Assets	$	14
Issuance of the 2026 Senior Notes in the third quarter of 2016	11
Issuance of new project level debt in the second half of 2016 and 2017 partially offset by the lower principal balances on project level debt in 2017	1
Higher borrowings in 2016 on the revolving credit facility	(5		)
	$	21

Income Attributable to Noncontrolling Interests

For the year ended December 31, 2017, the Company had a loss of $75 million attributable to noncontrolling interests with respect to its tax equity financing arrangements and the application of the HLBV method.

Consolidated Results of Operations

2016 compared to 2015

The following table provides selected financial information:



	Year ended December 31,
(In millions)	2016			2015			Change
Operating Revenues
Energy and capacity revenues	$	1,104		$	1,024		$	80
Contract amortization	(69		)	(54		)	(15		)
Mark-to-market economic hedging activities	—			(2		)	2
Total operating revenues	1,035			968			67
Operating Costs and Expenses
Cost of fuels	61			71			(10		)
Emissions credit amortization	6			—			6
Operations and maintenance	176			180			(4		)
Other costs of operations	65			72			(7		)
Depreciation and amortization	303			303			—
Impairment losses	185			1			184
General and administrative	14			10			4
Acquisition-related transaction and integration costs	1			3			(2		)
Total operating costs and expenses	811			640			171
Operating Income	224			328			(104		)
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	60			31			29
Other income, net	3			3			—
Loss on debt extinguishment	—			(9		)	9
Interest expense	(272		)	(258		)	(14		)
Total other expense, net	(209		)	(233		)	24
Net Income	15			95			(80		)
Less: Net (loss) income attributable to noncontrolling interests	(111		)	(62		)	(49		)
Net Income Attributable to NRG Yield LLC	$	126		$	157		$	(31	)



	Year ended December 31,
Business metrics:	2016	2015
Renewables MWh generated/sold (in thousands) ^(a)	7,291	6,463
Conventional MWh generated (in thousands) ^(a)(b)	1,697	2,487
Thermal MWt sold (in thousands)	1,966	1,946
Thermal MWh sold (in thousands) ^(c)	71	297

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

^(b)Volumes generated are not sold as the Conventional facilities sell capacity rather than energy.

^(c)MWh sold do not include 204 MWh generated by NRG Dover, a subsidiary of the Company, under the PPA with NRG Power Marketing during the year ended December 31, 2016, respectively, as further described in Item 15 — Note 13, Related Party Transactions, to the Consolidated Financial Statements.

Management’s discussion of the results of operations for the years ended December 31, 2016 and 2015

Gross Margin

Economic Gross Margin

The following tables present the composition of gross margin, as well as the reconciliation to economic gross margin for the years ended December 31, 2016 and 2015:



	Conventional			Renewables			Thermal			Total
(In millions)
Year ended December 31, 2016
Energy and capacity revenues	$	338		$	594		$	172		$	1,104
Cost of fuels	(1		)	—			(60		)	(61		)
Contract amortization	(5		)	(62		)	(2		)	(69		)
Emissions credit amortization	(6		)	—			—			(6		)
Gross margin	$	326		$	532		$	110		$	968
Contract amortization	5			62			2			69
Emissions credit amortization	6			—			—			6
Economic gross margin	$	337		$	594		$	112		$	1,043

Year ended December 31, 2015
Energy and capacity revenues	$	341		$	507		$	176		$	1,024
Cost of fuels	(1		)	(1		)	(69		)	(71		)
Contract amortization	(5		)	(47		)	(2		)	(54		)
Mark-to-market for economic hedging activities	—			(2		)	—			(2		)
Gross margin	$	335		$	457		$	105		$	897
Contract amortization	5			47			2			54
Mark-to-market for economic hedging activities	—			2			—			2
Economic gross margin	$	340		$	506		$	107		$	953

Gross margin increased by $71 million and economic gross margin increased by $90 million during the year ended December 31, 2016, compared to the same period in 2015, driven by:



Renewables:	(In millions)
26% increase in volume generated at the Alta wind projects, as well as a 7% increase in generation at other Wind projects. Additionally, there was an increase of $4 million in economic gross margin due to the acquisition of Spring Canyon in May 2015	$	61
Increase in average price per MWh due to higher pricing in the Alta X and XI PPAs which were effective in January 2016, compared with merchant prices in 2015	27
Thermal:
Higher sales volume in 2016 as a result of milder weather in 2015, as well as the completion of a project for a new customer in the second half of the year	5
Conventional:
Lower revenues at Walnut Creek as a result of forced outages in 2016, partially offset by higher revenues at El Segundo in 2016 as a result of forced outages in 2015	(3		)
Increase in economic gross margin	$	90
Higher contract amortization primarily for the Alta X and XI PPAs, which began in January 2016	(15		)
Emissions credit amortization of NOx allowances at Walnut Creek and El Segundo in compliance with amendments to the Regional Clean Air Incentives Market program	(6		)
Unrealized losses on forward contracts prior to the start of the PPA for Elbow Creek which began October 2015	2
Increase in gross margin	$	71

Operations and Maintenance Expense



	Conventional		Renewables		Thermal		Total
(In millions)
Year ended December 31, 2016	$	32	$	96	$	48	$	176
Year ended December 31, 2015	30		99		51		180

Operations and maintenance expense decreased by $4 million during the year ended December 31, 2016, compared to the same period in 2015, driven by:



	(In millions)
Increase in Conventional segment primarily due to Walnut Creek forced outages in 2016, compared to the forced outages at El Segundo in 2015	$	2
Decrease in Renewables segment primarily due to insurance proceeds received at Wildorado in 2016 in connection with a 2014 wind outage claim	(3		)
Decrease in Thermal segment primarily due to acceleration of maintenance work on thermal facilities into 2015	(3		)
	$	(4	)

Other Costs of Operations

Other costs of operations decreased by $7 million during the year ended December 31, 2016, compared to the same period in 2015, primarily due to lower assessments for property taxes at Alta X and XI and NRG Wind TE Holdco.

General and Administrative Expenses

General and administrative expenses increased by $4 million for the year ended December 31, 2016 compared to the same period in 2015, primarily due to new executive compensation in 2016, and an increase in base management fee for the Management Services Agreement with NRG in connection with the acquisition of the Drop Down Assets.

Impairment Losses

For the year ended December 31, 2016, the Company recorded impairment losses of $185 million, primarily due to the impairments of property, plant and equipment for Elbow Creek, Goat Wind, and Forward, as further described in Item 15 — Note 9, Asset Impairments, to the Consolidated Financial Statements, as well as in Critical Accounting Policies and Estimates in this Item 7 below. Because the projects were acquired from NRG and related to interests under common control by NRG, the property, plant and equipment for these assets was recorded at historical cost of $298 million rather than estimated fair value of $132 million at the acquisition date. The three projects were acquired as part of the November 2015 Drop Down Assets. As discussed in Item 15 — Note 3, Business Acquisitions, the historical cost for November 2015 Drop Down Assets was $369 million for the net assets, which was higher than the fair value paid of $207 million. The difference between the historical cost of net assets and the fair value paid for the November 2015 Drop Down Assets was recorded to contributed capital on the Company’s consolidated balance sheet.

Loss on Debt Extinguishment

A loss on debt extinguishment of $9 million was recorded for the year ended December 31, 2015, driven by the refinancing of the El Segundo credit facility and the termination of the interest rate swaps for Alta Wind X and XI in connection with the sale of an economic interest in Alta TE Holdco to a financial institution as further described in Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the Consolidated Financial Statements.

Equity in Earnings of Unconsolidated Affiliates

Equity in earnings of unconsolidated affiliates increased by $29 million during the year ended December 31, 2016, compared to the same period in 2015, primarily due to an increase in equity earnings from Desert Sunlight, which was acquired in June 2015, DGPV Holdco 1 and RPV Holdco, partially offset by losses from Elkhorn Ridge.

Interest Expense

Interest expense increased by $14 million during the year ended December 31, 2016, compared to the same period in 2015, due to:



	(In millions)
Amortization of the fair value of interest rate swaps primarily acquired with the January 2015 Drop Down Assets and November 2015 Drop Down Assets	$	10
Issuance of 2026 Senior Notes in August 2016	7
Utah Solar Portfolio debt assumed in connection with the March 2017 Drop Down Assets	6
Intercompany debt issued with Yield, Inc. in 2015, due 2020	5
Issuance of 2037 CVSR Holdco Notes in July 2016	4
Higher revolving credit facility borrowings in 2016	2
Repricing of project-level financing arrangements and lower principal balances	(20		)
	$	14

Income Attributable to Noncontrolling Interests

For the year ended December 31, 2016, the Company had a loss of $111 million attributable to noncontrolling interests with respect to its tax equity financing arrangements and the application of the HLBV method, which was primarily related to the impairment losses described above. For the year ended December 31, 2015, the Company had a loss of $62 million attributable to noncontrolling interests with respect to its tax equity financing arrangements and the application of the HLBV method.

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, service debt and pay distributions. 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.

Current Liquidity Position

As of December 31, 2017 and 2016, the Company's liquidity was approximately $680 million and $932 million, respectively, comprised of cash, restricted cash, and availability under the Company's revolving credit facility.



	As of December 31,
	2017		2016
	(In millions)
Cash and cash equivalents	$	146	$	321
Restricted cash - operating	86		76
Restricted cash - reserves	82		100
Total	314		497
Total credit facility availability	366		435
Total liquidity	$	680	$	932

The Company's liquidity includes $168 million and $176 million of restricted cash balances as of December 31, 2017 and 2016, respectively. Restricted cash consists primarily of funds to satisfy the requirements of certain debt arrangements and funds held within the Company's projects that are restricted in their use. Of these funds as of December 31, 2017, approximately $25 million is designated for current debt service payments, $25 million is designated to fund operating expenses and $36 million is designated for distributions to the Company, with the remaining $82 million restricted for reserves including debt service, performance obligations and other reserves, as well as capital expenditures.

The Company's various financing arrangements are described in Item 15 — Note 10, Long-term Debt, to the Consolidated Financial Statements. As of December 31, 2017, $55 million of borrowings and $74 million of letters of credit were outstanding under the revolving credit facility.

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; growth, operating and maintenance capital expenditures; and to fund distributions to Yield, Inc. and NRG. 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.

NRG Transaction and Related Liquidity Considerations

On February 6, 2018, NRG entered into agreements for the sale of 100% of its interest in NRG Yield, Inc. and its renewable energy development and operations platform, or the NRG Transaction. In connection with this, the Company entered into a Consent and Indemnity Agreement with NRG and Global Infrastructure Partners. For further discussion of the NRG Transaction and the related ROFO impacts, refer to Item 1 — Business, as well as, Item 15 — Note 1, Nature of Business.

As part of the Consent and Indemnity Agreement, GIP has arranged a $1.5 billion backstop credit facility to manage any change of control costs associated with NRG Yield's corporate debt. In addition, GIP has committed to provide $400 million in financing support for the Carlsbad Energy Center transaction, which would be exercised if necessary.

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. As of December 31, 2017, the Company's 2024 Senior Notes and 2026 Senior Notes are rated BB by S&P and Ba2 by Moody's. The ratings outlook is stable.

On February 7, 2018, S&P and Moody's reaffirmed the ratings outlook as stable.

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 by Yield, Inc. or the Company as appropriate given market conditions. As described in Item 15— Note 10, Long-term Debt, to the Consolidated Financial Statements, and above in Significant Events During the Year Ended December 31, 2017, the Company's financing arrangements consist of the revolving credit facility, the 2024 Senior Notes, the 2026 Senior Notes, its intercompany borrowings with Yield, Inc. and project-level financings for its various assets.

At-the-Market Equity Offering Program

In 2016, NRG Yield, Inc. entered into an equity distribution agreement, or EDA, with Barclays Capital Inc., Credit Suisse Securities (USA) LLC, J.P. Morgan Securities LLC and RBC Capital Markets, LLC, as sales agents. Pursuant to the terms of the EDA, NRG Yield, Inc. may offer and sell shares of its Class C common stock par value $0.01 per share, from time to time through the sales agents, as NRG Yield, Inc.’s sales agents for the offer and sale of the shares, up to an aggregate sales price of $150,000,000 through an at-the-market equity offering program, or ATM Program. NRG Yield, Inc. may also sell shares of its Class C common stock to any of the sales agents, as principals for its own account, at a price agreed upon at the time of sale. As of December 31, 2017, Yield, Inc. issued 1,921,866 shares of Class C common stock under the ATM Program for gross proceeds of $35 million and incurred commission fees of $346 thousand. At December 31, 2017, approximately $115 million of Class C common stock remains available for issuance under the ATM Program. Yield, Inc. used the net proceeds to acquire 1,921,866 Class C units from Yield LLC.

Thermal Financing

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 Item 15 — Note 10, Long-term Debt to the Consolidated Financial Statements; (ii) capital expenditures; (iii) acquisitions and investments; and (iv) distributions.

Debt Service Obligations

Principal payments on debt as of December 31, 2017, are due in the following periods:



Description	2018		2019		2020		2021		2022		There - after		Total
	(In millions)
Long-term debt - affiliate, due 2019	$	—	$	337	$	—	$	—	$	—	$	—	$	337
Long-term debt - affiliate, due 2020	—		—		281		—		—		—		281
NRG Yield Operating LLC Senior Notes, due 2024	—		—		—		—		—		500		500
NRG Yield Operating LLC Senior Notes, due 2026	—		—		—		—		—		350		350
NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, due 2019	—		55		—		—		—		—		55
Total Corporate-level debt	—		392		281		—		—		850		1,523
Project-level debt:
Agua Caliente Borrower 2, due 2038	1		1		1		1		1		36		41
Alpine, due 2022	8		8		8		8		103		—		135
Alta Wind I - V lease financing arrangements, due 2034 and 2035	40		41		45		45		47		708		926
CVSR, due 2037	26		24		21		23		25		627		746
CVSR Holdco Notes, due 2037	6		6		6		7		9		160		194
El Segundo Energy Center, due 2023	48		49		53		57		63		130		400
Energy Center Minneapolis, due 2025	7		11		11		11		11		32		83
Energy Center Minneapolis Series D Notes, due 2031	—		—		—		—		—		125		125
Laredo Ridge, due 2028	5		5		6		6		7		66		95
Marsh Landing, due 2023	55		57		60		62		65		19		318
Tapestry, due 2021	11		11		11		129		—		—		162
Utah Solar Portfolio, due 2022	12		14		13		13		226		—		278
Viento, due 2023	16		18		16		16		17		80		163
Walnut Creek, due 2023	45		47		49		52		55		19		267
Other	26		30		69		25		24		269		443
Total project-level debt	306		322		369		455		653		2,271		4,376
Total debt	$	306	$	714	$	650	$	455	$	653	$	3,121	$	5,899

Capital Expenditures

The Company's capital spending program is mainly focused on maintenance capital expenditures, consisting of costs to maintain the assets currently operating, such as costs to replace or refurbish assets during routine maintenance, and growth capital expenditures, consisting of costs to construct new assets, costs to complete the construction of assets where construction is in process, and capital expenditures related to acquiring additional thermal customers. For the years ended December 31, 2017, 2016, and 2015, the Company used approximately $31 million, $20 million, and $29 million, respectively, to fund capital expenditures, including maintenance capital expenditures of $27 million, $16 million and $20 million, respectively. Growth capital expenditures in 2017 were in primarily in the Thermal segment and relate to servicing new customers in district energy centers. Growth capital expenditures in 2016 and 2015 primarily related to the servicing new customers in district energy centers within the Thermal segment and construction of the Company's solar generating assets. The Company develops annual capital spending plans based on projected requirements for maintenance and growth capital. The Company estimates $32 million of maintenance expenditures for 2018. These estimates are subject to continuing review and adjustment and actual capital expenditures may vary from these estimates.

Acquisitions and Investments

The Company intends to acquire generation and thermal infrastructure assets developed and constructed by NRG or other third parties in the future, as well as generation and thermal infrastructure assets from third parties where the Company believes its knowledge of the market and operating expertise provides a competitive advantage, and to utilize such acquisitions as a means to grow its CAFD.

On February 24, 2017, the Company amended and restated the ROFO Agreement, expanding the ROFO Assets pipeline with the addition of 234 net MW of utility-scale solar projects, consisting of Buckthorn Solar, a 154 net MW solar facility in Texas, and Hawaii solar projects, which have a combined capacity of 80 net MW.

On February 6, 2018, the Company entered into an agreement with NRG to purchase 100% of the membership interests in Carlsbad Energy Holdings LLC, which indirectly owns the Carlsbad project, a 527 MW natural gas fired project in Carlsbad, CA, pursuant to the ROFO Agreement. The purchase price for the transaction is $365 million in cash consideration, subject to customary working capital and other adjustments. The transaction is expected to close during the fourth quarter of 2018 and is contingent upon the consummation of the NRG Transaction.

On January 24, 2018, the Company entered into an agreement with NRG to purchase 100% of NRG's ownership interest in Buckthorn Solar pursuant to the ROFO Agreement for cash consideration of $42 million, subject to other adjustments. The transaction is expected to close during the first quarter of 2018.

As discussed in Item 1 — Note 3, Business Acquisitions, the Company completed the following acquisitions in 2017:

November 2017 Drop Down Assets — On November 1, 2017, the Company acquired a 38 MW solar portfolio primarily comprised of assets from NRG's Solar Power Partners (SPP) funds and other projects developed by NRG, for cash consideration of $74 million, including a working capital adjustment of $3 million, plus assumed non-recourse debt of $26 million.

August 2017 Drop Down Assets — On August 1, 2017, the Company acquired the remaining 25% interest in NRG Wind TE Holdco, a portfolio of 12 wind projects, from NRG for total cash consideration of $44 million, including a working capital adjustment of $3 million. The transaction also includes potential additional payments to NRG dependent upon actual energy prices for merchant periods beginning in 2027.

Investment Partnership with NRG

On September 26, 2017, the Company entered into an additional partnership with NRG by forming NRG DGPV Holdco 3 LLC, or DGPV Holdco 3, in which the Company would invest up to $50 million in an operating portfolio of distributed solar assets, primarily comprised of community solar projects, developed by NRG. The Company owns approximately 43 MW of distributed solar capacity, based on cash to be distributed, with a weighted average contract life of approximately 20 years as of December 31, 2017.

During the year ended December 31, 2017, the Company invested $64 million in distributed generation partnerships with NRG.

Cash Distributions to Yield, Inc. and NRG

The Company intends to distribute to its unit holders in the form of a quarterly distribution all of the CAFD 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. CAFD is defined as net income before interest expense, income taxes, depreciation and amortization, plus cash distributions from unconsolidated affiliates, cash receipts from notes receivable, less cash distributions to noncontrolling interests, maintenance capital expenditures, pro-rata EBITDA from unconsolidated affiliates, cash interest paid, income taxes paid, principal amortization of indebtedness and changes in prepaid and accrued capacity payments. Distributions on units 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 distributions will continue to be paid in the foreseeable future.

The following table lists the distributions paid on the Company's Class A, Class B, Class C and Class D units during the year ended December 31, 2017:



	Fourth Quarter 2017		Third Quarter 2017		Second Quarter 2017		First Quarter 2017
Distributions per Class A and Class B unit	$	0.288	$	0.28	$	0.27	$	0.26
Distributions per Class C and Class D unit	$	0.288	$	0.28	$	0.27	$	0.26

On February 15, 2018, the Company declared a quarterly distribution on its Class A, Class B, Class C and Class D units of $0.298 per unit payable on March 15, 2018.

Cash Flow Discussion

Year Ended December 31, 2017 Compared to Year Ended December 31, 2016

The following table reflects the changes in cash flows for the year ended December 31, 2017, compared to 2016:



Year ended December 31,	2017			2016			Change
(In millions)
Net cash provided by operating activities	$	516		$	577		$	(61	)
Net cash used in investing activities	(283		)	(131		)	(152		)
Net cash used in financing activities	(416		)	(202		)	(214		)

Net Cash Provided By Operating Activities



Changes to net cash provided by operating activities were driven by:	(In millions)
Decrease in operating income adjusted for non-cash items driven by primarily by lower revenues in the Renewables segment in 2017 compared to 2016	$	(63	)
Decrease in working capital driven primarily by the timing of accounts receivable collections, and inventory build up in the Renewables segment in connection with the transition to self operations, as well as higher prepaid expenses in 2017 compared to 2016	(12		)
Higher distributions from unconsolidated affiliates primarily due to the acquisition of the Utah Solar Portfolio, which was acquired by the Company in March 2017 and by NRG in November 2016	14
	$	(61	)

Net Cash Used In Investing Activities



Changes to net cash used in investing activities were driven by:	(In millions)
Payments for the acquisition of the March 2017, August 2017, and November 2017 Drop Down Assets in 2017 compared to the payments made for the CVSR Drop Down in 2016	$	(173	)
Higher return of investment from unconsolidated affiliates combined with lower investments primarily in DGPV HoldCo entities in 2017	29
Higher capital expenditures primarily related to maintenance capital expenditures at Walnut Creek as a result of the forced outages in 2017	(11		)
Higher insurance proceeds in 2017 in the Conventional segment compared to the insurance proceeds in 2016 in the Renewables segment	3
	$	(152	)

Net Cash Used In Financing Activities



Changes in net cash used in financing activities were driven by:	(In millions)
Increase in net contributions from noncontrolling interests due to higher production-based payments in 2017 compared to 2016	$	8
Lower net payments of distributions to NRG for the Drop Down Assets relating to the pre-acquisition period in 2017 compared to 2016	164
Proceeds from the issuance of Class C units	33
Net payments of $306 million under the revolving credit facility in 2016 compared to proceeds of $55 million in 2017	361
Higher borrowing in 2016, primarily related to the 2026 Senior Notes and CVSR Holdco Notes due 2037 partially offset by higher repayments of long-term debt in 2017	(751		)
Increase in distributions paid to unit holders	(29		)
	$	(214	)

Year Ended December 31, 2016 Compared to Year Ended December 31, 2015

The following table reflects the changes in cash flows for the year ended December 31, 2016, compared to 2015:



Year ended December 31,	2016			2015			Change
(In millions)
Net cash provided by operating activities	$	577		$	424		$	153
Net cash used in investing activities	(131		)	(1,098		)	967
Net cash (used in) provided by financing activities	(202		)	354			(556		)

Net Cash Provided By Operating Activities



Changes to net cash provided by operating activities were driven by:	(In millions)
Increase in operating income adjusted for non-cash items driven by higher revenues mainly in the Renewables segment in 2016 compared to 2015	$	120
Changes in working capital driven primarily by the timing of accounts receivable collections in 2015 compared to 2016	35
Lower distributions from unconsolidated affiliates	(2		)
	$	153

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, in 2015	$	37
Higher payments for the acquisition of the January 2015 and November 2015 Drop Down Assets in 2015 compared to the payments made for the CVSR Drop Down in 2016	621
Decrease in capital expenditures primarily due to the completion of a project in the Thermal segment in 2015, as well as lower maintenance capital expenditures in 2016	9
Higher net investments in unconsolidated affiliates in 2015, primarily due to investment in Desert Sunlight	305
Other	(5		)
	$	967

Net Cash (Used In) Provided By Financing Activities



Changes in net cash provided by financing activities were driven by:	(In millions)
Higher payments of distributions to NRG from Drop Down Assets prior to the acquisition dates	$	(105	)
Proceeds from sale of an economic interest in Alta TE Holdco in 2015, as further described in Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, compared to lower net contributions from tax equity investors in 2016	(117		)
Proceeds from the issuance of Class C units in 2015	(599		)
Increase in distributions paid to unit holders	(34		)
Net repayments of $306 million under the revolving credit facility in 2016 compared to the net borrowings of $306 million in 2015	(612		)
Issuance of the Series D Notes in October 2016, 2026 Senior Notes in August 2016, and CVSR Holdco Notes, due 2037 in July 2016, partially offset by lower debt principal payments throughout 2016, compared to 2015	919
Higher debt issuance costs paid in 2016	(8		)
	$	(556	)

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 December 31, 2017, 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. NRG DGPV Holdco 1 LLC, NRG DGPV Holdco 2 LLC, NRG DGPV Holdco 3 LLC, NRG RPV Holdco 1 LLC and GenConn are 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 $777 million as of December 31, 2017. This indebtedness may restrict the ability of these subsidiaries to issue dividends or distributions to the Company. See also Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the Consolidated Financial Statements.

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 the Company's capital expenditure programs. The following table summarizes the Company's contractual obligations. See Item 15 — Note 10, Long-term Debt and Note 14, Commitments and Contingencies, to the Consolidated Financial Statements for additional discussion.



	By Remaining Maturity at December 31,
	2017										2016
Contractual Cash Obligations	Under 1 Year		1-3 Years		3-5 Years		Over 5 Years		Total		Total
	(In millions)
Long-term debt (including estimated interest)	$	593	$	1,856	$	1,500	$	3,907	$	7,856	$	8,328
Operating leases	9		18		18		151		196		199
Fuel purchase and transportation obligations	11		8		6		16		41		45
Other liabilities ^(a)	29		45		29		105		208		129
Total	$	642	$	1,927	$	1,553	$	4,179	$	8,301	$	8,701

^(a)Includes water right agreements, service and maintenance agreements, and LTSA commitments.

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 of 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 December 31, 2017, based on their level within the fair value hierarchy defined in ASC 820; and indicate the maturities of contracts at December 31, 2017. For a full discussion of the Company's valuation methodology of its contracts, see Derivative Fair Value Measurements in Item 15 — Note 6, Fair Value of Financial Instruments, to the Consolidated Financial Statements.



Derivative Activity (Losses)/Gains	(In millions)
Fair value of contracts as of December 31, 2016	$	(76	)
Contracts realized or otherwise settled during the period	32
Changes in fair value	(2		)
Fair value of contracts as of December 31, 2017	$	(46	)

Fair value of contracts as of December 31, 2017

Maturity

Fair Value Hierarchy 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 2

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 GAAP. The preparation of these financial statements and related disclosures in compliance with 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. 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 Item 15 — Note 2, Summary of Significant Accounting Policies, to the Consolidated Financial Statements. 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 impairment of long lived assets and other intangible assets and acquisition accounting.



Accounting Policy	Judgments/Uncertainties Affecting Application

Impairment of Long Lived Assets	Recoverability of investments through future operations
	Regulatory and political environments and requirements
	Estimated useful lives of assets
	Operational limitations and environmental obligations
	Estimates of future cash flows
	Estimates of fair value
	Judgment about triggering events
Acquisition Accounting	Identification of intangible assets acquired
	Inputs for fair value of assets and liabilities acquired
	Application of various methodologies

Evaluation of Assets for Impairment and Other-Than-Temporary Decline in Value

In accordance with ASC 360, Property, Plant, and Equipment, or ASC 360, property, plant and equipment and certain intangible assets are evaluated for impairment whenever indicators of impairment exist. Examples of such indicators or events are:


•	Significant decrease in the market price of a long-lived asset;


•	Significant adverse change in the manner an asset is being used or its physical condition;


•	Adverse business climate;


•	Accumulation of costs significantly in excess of the amount originally expected for the construction or acquisition of an asset;


•	Current-period loss combined with a history of losses or the projection of future losses; and


•	Change in the Company's intent about an asset from an intent to hold to a greater than 50% likelihood that an asset will be sold or disposed of before the end of its previously estimated useful life.

Recoverability of assets to be held and used is measured by a comparison of the carrying amount of the assets to the future net cash flows expected to be generated by the asset, through considering project specific assumptions for long-term power pool prices, escalated future project operating costs and expected plant operations. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. The fair value may be determined by factoring in the probability weighting of different courses of action available to the Company as appropriate. Generally, fair value will be determined using valuation techniques such as the present value of expected future cash flows or comparable values determined by transactions in the market. The Company uses its best estimates in making these evaluations and considers various factors, including forward price curves for energy, fuel costs and operating costs. However, actual future market prices and project costs could vary from the assumptions used in the Company's estimates, and the impact of such variations could be material.

Annually, during the fourth quarter, the Company revises its views of power prices, including the Company's fundamental view for long-term power prices, forecasted generation and operating and capital expenditures, in connection with the preparation of its annual budget.

The Company recorded certain long-lived asset impairments in 2017 and 2016, as described in Item 15 — Note 9, Asset Impairments, to the Consolidated Financial Statements, with respect to several wind projects.

During the fourth quarter of 2017, as the Company updated its estimated cash flows in connection with the preparation and review of the Company's annual budget, the Company determined that the cash flows for the Elbow Creek and Forward facilities were below the carrying value of the related assets, primarily driven by continued declining merchant power prices in post-contract periods, and that the assets were considered impaired. The fair value of the facilities was determined using an income approach by applying a discounted cash flow methodology to the long-term budgets for each respective plant. The income approach utilizes estimates of discounted future cash flows, which include key inputs, such as forecasted power prices, operations and maintenance expense, and discount rates. The Company measured the impairment loss as the difference between the carrying amount and the fair value of the assets and recorded impairment losses of $26 million and $5 million for Elbow Creek and Forward, respectively.

The Company is also required to evaluate its equity method investments to determine whether or not they are impaired. ASC 323, Investments - Equity Method and Joint Ventures, or ASC 323, provides the accounting requirements for these investments. The standard for determining whether an impairment must be recorded under ASC 323 is whether the value is considered to be an other-than-temporary decline in value. The evaluation and measurement of impairments under ASC 323 involves the same uncertainties as described for long-lived assets that the Company owns directly and accounts for in accordance with ASC 360. Similarly, the estimates that the Company makes with respect to its equity method investments are subjective, and the impact of variations in these estimates could be material. Additionally, if the projects in which the Company holds these investments recognize an impairment under the provisions of ASC 360, the Company would record its proportionate share of that impairment loss and would evaluate its investment for an other-than-temporary decline in value under ASC 323.

Certain of the Company’s projects have useful lives that extend well beyond the contract period and therefore, management’s view of long-term power prices in the post-contract periods may have a significant impact on the expected future cash flows for these projects. Accordingly, if management’s view of long-term power prices in certain markets continues to decrease, it is possible that some of the Company’s other long-lived assets may be impaired.

Acquisition Accounting

The Company applies ASC 805, Business Combinations, when accounting for the acquisition of a business, with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the acquisition date. The Company completes the accounting for an acquisition when the evaluations are completed to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date. The allocation of the purchase price may be modified up to one year from the date of the acquisition as more information is obtained about the fair value of assets acquired and liabilities assumed. Consideration is measured based on fair value of the assets transferred to the seller.

Significant judgment is required in determining the acquisition date fair value of the assets acquired and liabilities assumed, predominantly with respect to property, plant and equipment, power purchase agreements, asset retirement obligations and other contractual arrangements. Evaluations include numerous inputs including forecasted cash flows that incorporate the specific attributes of each asset including age, useful life, equipment condition and technology, as well as current replacement costs for similar assets. Other key inputs that require judgment include discount rates, comparable market transactions, estimated useful lives and probability of future transactions. The Company evaluates all available information, as well as all appropriate methodologies when determining the fair value of assets acquired and liabilities assumed in a business combination. In addition, once the appropriate fair values are determined, the Company must determine the remaining useful life for property, plant and equipment and the amortization period and method of amortization for each finite-lived intangible asset.

The Company must apply ASC 805-50, Business Combinations - Related Issues, when it acquires an interest from NRG. The assets and liabilities transferred to the Company related to interests under common control by NRG must be recorded at historical cost, with the difference between the amount paid and the historical value of the related equity recorded as a distribution to or contribution from NRG with the offset to noncontrolling interest. Economics may change in the years subsequent to NRG’s construction or acquisition of certain assets, and although the Company may acquire these assets from NRG based on a different valuation, the Company must record the assets at historical cost. These changes in economics may impact the amount that the Company pays for the assets but will not alter the carrying amount. Accordingly, significant changes in the economics related to these assets may trigger a requirement for impairment testing.

Recent Accounting Developments

See Item 15 — Note 2, Summary of Significant Accounting Policies, to the Consolidated Financial Statements for a discussion of recent accounting developments.

Item 7A — 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. See Item 15 — Note 7, Accounting for Derivative Instruments and Hedging Activities, to the Consolidated Financial Statements for more information.

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 a change of approximately $1 million in the net value of derivatives as of December 31, 2017.

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. See item 15 — Note 7, Accounting for Derivative Instruments and Hedging Activities, to the Consolidated Financial Statements for more information.

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 Item 15 — Note 10, Long-term Debt, to the Consolidated Financial Statements for more information about interest rate swaps of the Company's project subsidiaries.

If all of the above swaps had been discontinued on December 31, 2017, the Company would have owed the counterparties $50 million. Based on the credit ratings 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 December 31, 2017, 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 December 31, 2017, the fair value of the Company's debt was $5,915 million and the carrying value was $5,899 million. The Company estimates that a 1% decrease in market interest rates would have increased the fair value of its long-term debt by $306 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. See Item 15 — Note 1, Nature of Business, and Note 6, Fair Value of Financial Instruments, to the Consolidated Financial Statements for more information about concentration of credit risk.

Item 8 — Financial Statements and Supplementary Data

The financial statements and schedules are listed in Part IV, Item 15 of this Form 10-K.

Item 9 — Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

None.

Item 9A — Controls and Procedures

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures and Internal Control Over Financial Reporting

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 report on Form 10-K.

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 fourth quarter of 2017 that materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Inherent Limitations over Internal Controls

The Company's internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial statements for external purposes in accordance with GAAP. The Company's internal control over financial reporting includes those policies and procedures that:

1. Pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the Company's assets;

2. Provide reasonable assurance that transactions are recorded as necessary to permit preparation of consolidated financial statements in accordance with GAAP, and that the Company's receipts and expenditures are being made only in accordance with authorizations of its management and directors; and

3. Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company's assets that could have a material effect on the consolidated financial statements.

Internal control over financial reporting cannot provide absolute assurance of achieving financial reporting objectives because of its inherent limitations, including the possibility of human error and circumvention by collusion or overriding of controls. Accordingly, even an effective internal control system may not prevent or detect material misstatements on a timely basis. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate.

Management's Report on Internal Control over Financial Reporting

The Company's management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). 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 its internal control over financial reporting based on the framework in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the Company's evaluation under the framework in Internal Control — Integrated Framework (2013), the Company's management concluded that its internal control over financial reporting was effective as of December 31, 2017.

Item 9B — Other Information

None.

PART III

Item 10 — Directors, Executive Officers and Corporate Governance

Item 10 has been omitted from this report pursuant to the reduced disclosure format permitted by General Instruction I to Form 10-K.

Item 11 — Executive Compensation

Item 11 has been omitted from this report pursuant to the reduced disclosure format permitted by General Instruction I to Form 10-K.

Item 12 — Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Item 12 has been omitted from this report pursuant to the reduced disclosure format permitted by General Instruction I to Form 10-K.

Item 13 — Certain Relationships and Related Transactions, and Director Independence

Item 13 has been omitted from this report pursuant to the reduced disclosure format permitted by General Instruction I to Form 10-K.

Item 14 — Principal Accounting Fees and Services

Audit and Nonaudit Fees

The following table presents fees for professional services rendered by KPMG LLP, the Company's principal independent registered public accounting firm, for the years ended December 31, 2017 and December 31, 2016.



	Year Ended December 31,
	2017		2016
Audit Fees	$	1,916,700	$	1,952,210
Audit-Related Fees	—		—
Tax Fees	12,700		79,269
All Other Fees	—		—
Total	$	1,929,400	$	2,031,479

Audit Fees

For 2017 and 2016 audit services, KPMG LLP billed the Company approximately $1,916,700 and $1,952,210, respectively, for the audit of the Company’s consolidated financial statements and the review of the Company’s quarterly consolidated financial statements on Form 10-Q that are customary under the standards of the Public Company Accounting Oversight Board (United States), and in connection with statutory audits.

Audit-Related Fees

There were no audit-related fees billed to the Company by KPMG LLP for 2017 or 2016.

Tax Fees

There were approximately $12,700 in tax fees billed to the Company by KPMG LLP for 2017, relating mainly to compliance work. There were approximately $79,269 in tax fees billed to the Company by KPMG LLP for 2016.

All Other Fees

There were no other fees billed to the Company by KPMG LLP for 2017 or 2016.

Policy on Audit Committee Pre-approval

The Audit Committee of Yield, Inc. is responsible for appointing, setting compensation for, and overseeing the work of the independent registered public accounting firm of the Company. The Audit Committee of Yield, Inc. has established a policy regarding pre-approval of all audit and permissible nonaudit services provided by the independent registered public accounting firm of the Company.

The Audit Committee of Yield, Inc. will annually review and pre-approve services that are expected to be provided by the independent registered public accounting firm. The term of the pre-approval will be 12 months from the date of the pre-approval, unless the Audit Committee of Yield, Inc. approves a shorter time period. The Audit Committee may periodically amend and/or supplement the pre-approved services based on subsequent determinations.

Unless the Audit Committee of Yield, Inc. has pre-approved Audit Services or a specified category of nonaudit services, any engagement to provide such services must be pre-approved by the Audit Committee of Yield, Inc. if it is to be provided by the independent registered public accounting firm. The Audit Committee of Yield, Inc. must also pre-approve any proposed services exceeding the pre-approved budgeted fee levels for a specified type of service.

The Audit Committee of Yield, Inc. has authorized its Chair to pre-approve services in amounts up to $100,000 per engagement. Engagements exceeding $100,000 must be approved by the full Audit Committee of Yield, Inc. Engagements pre-approved by the Chair are reported to the Audit Committee of Yield, Inc. at its next scheduled meeting.

PART IV

Item 15 — Exhibits, Financial Statement Schedules

(a)(1) Financial Statements

The following consolidated financial statements of NRG Yield LLC and related notes thereto, together with the reports thereon of KPMG LLP, are included herein:

Consolidated Statements of Operations — Years ended December 31, 2017, 2016 and 2015

Consolidated Statements of Comprehensive Income — Years ended December 31, 2017, 2016 and 2015

Consolidated Balance Sheets — As of December 31, 2017 and 2016

Consolidated Statements of Cash Flows — Years ended December 31, 2017, 2016 and 2015

Consolidated Statements of Members' Equity — Years ended December 31, 2017, 2016 and 2015

Notes to Consolidated Financial Statements

(a)(2) Not applicable

(a)(3) Exhibits: See Exhibit Index submitted as a separate section of this report

(b) Exhibits

See Exhibit Index submitted as a separate section of this report

Report of Independent Registered Public Accounting Firm

The Members

NRG Yield LLC:

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of NRG Yield LLC and subsidiaries (the “Company”) as of December 31, 2017 and 2016, the related consolidated statements of operations, comprehensive income, members’ equity, and cash flows for each of the years in the three‑year period ended December 31, 2017, and the related notes (collectively, the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for each of the years in the three‑year period ended December 31, 2017, in conformity with U.S. generally accepted accounting principles.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

(signed) KPMG LLP

We have served as the Company’s auditor since 2012.

Philadelphia, Pennsylvania

March 1, 2018

NRG YIELD LLC

CONSOLIDATED STATEMENTS OF OPERATIONS



	Year ended December 31,
(In millions)	2017			2016 ^(a)			2015 ^(a)
Operating Revenues
Total operating revenues	$	1,009		$	1,035		$	968
Operating Costs and Expenses
Cost of operations	326			308			323
Depreciation and amortization	334			303			303
Impairment losses	44			185			1
General and administrative	19			14			10
Acquisition-related transaction and integration costs	3			1			3
Total operating costs and expenses	726			811			640
Operating Income	283			224			328
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	71			60			31
Other income, net	4			3			3
Loss on debt extinguishment	(3		)	—			(9		)
Interest expense	(293		)	(272		)	(258		)
Total other expense, net	(221		)	(209		)	(233		)
Net Income	62			15			95
Less: Net loss attributable to noncontrolling interests	(75		)	(111		)	(62		)
Net Income Attributable to NRG Yield LLC	$	137		$	126		$	157

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

See accompanying notes to consolidated financial statements.

NRG YIELD LLC

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME



	Year ended December 31,
	2017			2016 ^(a)			2015 ^(a)
(In millions)
Net Income	$	62		$	15		$	95
Other Comprehensive Income (Loss)
Unrealized gain (loss) on derivatives	17			13			(17		)
Other comprehensive income (loss)	17			13			(17		)
Comprehensive Income	79			28			78
Less: Comprehensive loss attributable to noncontrolling interests	(75		)	(111		)	(63		)
Comprehensive Income Attributable to NRG Yield LLC	$	154		$	139		$	141

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

See accompanying notes to consolidated financial statements.

NRG YIELD LLC

CONSOLIDATED BALANCE SHEETS



	December 31, 2017			December 31, 2016^(a)
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	146		$	321
Restricted cash	168			176
Accounts receivable — trade	96			96
Inventory	39			39
Notes receivable — current	13			16
Prepayments and other current assets	19			22
Total current assets	481			670
Property, plant and equipment, net	5,204			5,554
Other Assets
Equity investments in affiliates	1,178			1,152
Intangible assets, net	1,228			1,303
Other non-current assets	63			67
Total other assets	2,469			2,522
Total Assets	$	8,154		$	8,746
LIABILITIES AND MEMBERS' EQUITY
Current Liabilities
Current portion of long-term debt — external	$	306		$	323
Accounts payable — trade	27			23
Accounts payable — affiliate	48			40
Derivative instruments	17			33
Accrued expenses and other current liabilities	87			85
Total current liabilities	485			504
Other Liabilities
Long-term debt — external	4,921			5,128
Long-term debt — affiliate	618			618
Accounts payable — affiliate	—			9
Derivative instruments	31			46
Other non-current liabilities	91			77
Total non-current liabilities	5,661			5,878
Total Liabilities	6,146			6,382
Commitments and Contingencies
Members' Equity
Contributed capital	1,897			2,179
Retained earnings	17			44
Accumulated other comprehensive loss	(68		)	(85		)
Noncontrolling interest	162			226
Total Members' Equity	2,008			2,364
Total Liabilities and Members’ Equity	$	8,154		$	8,746

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

See accompanying notes to consolidated financial statements.

NRG YIELD LLC

CONSOLIDATED STATEMENTS OF CASH FLOWS



	Year ended December 31,
	2017			2016 ^(a)			2015 ^(a)
	(In millions)
Cash Flows from Operating Activities
Net (loss) income	$	62		$	15		$	95
Adjustments to reconcile net income to net cash provided by operating activities:
Equity in earnings of unconsolidated affiliates	(71		)	(60		)	(31		)
Distributions from unconsolidated affiliates	72			58			60
Depreciation and amortization	334			303			303
Amortization of financing costs	13			8			7
Amortization of intangibles and out-of-market contracts	70			76			55
Loss on debt extinguishment	3			—			9
Impairment losses	44			185			1
Changes in derivative instruments	(16		)	(15		)	(44		)
Loss on disposal of asset components	16			6			3
Cash provided by (used in) changes in other working capital:
Changes in prepaid and accrued capacity payments	(4		)	(8		)	(12		)
Changes in other working capital	(7		)	9			(22		)
Net Cash Provided by Operating Activities	516			577			424
Cash Flows from Investing Activities
Acquisition of businesses, net of cash acquired	—			—			(37		)
Acquisition of Drop Down Assets, net of cash acquired	(250		)	(77		)	(698		)
Capital expenditures	(31		)	(20		)	(29		)
Cash receipts from notes receivable	17			17			17
Return of investment from unconsolidated affiliates	47			28			42
Investments in unconsolidated affiliates	(73		)	(83		)	(402		)
Other	7			4			9
Net Cash Used in Investing Activities	(283		)	(131		)	(1,098		)
Cash Flows from Financing Activities
Net contributions from noncontrolling interests	13			5			122
Net distributions and return of capital to NRG prior to the acquisition of Drop Down Assets	(20		)	(184		)	(79		)
Proceeds from the issuance of class C units	33			—			599
Payments of distributions	(202		)	(173		)	(139		)
Proceeds from the revolving credit facility	55			60			551
Payments for the revolving credit facility	—			(366		)	(245		)
Proceeds from issuance of long-term debt — external	41			740			6
Proceeds from issuance of long-term debt — affiliate	—			—			281
Payments of debt issuance costs	(4		)	(15		)	(7		)
Payments for long-term debt — external	(332		)	(269		)	(735		)
Net Cash (Used in) Provided by Financing Activities	(416		)	(202		)	354
Net (Decrease) Increase in Cash and Cash Equivalents	(183		)	244			(320		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	497			253			573
Cash, Cash Equivalents and Restricted Cash at End of Period	$	314		$	497		$	253

Supplemental Disclosures
Interest paid, net of amount capitalized	$	(297	)	$	(271	)	$	(279	)
Non-cash investing and financing activities:
Additions to fixed assets for accrued capital expenditures	4			3			3
Non-cash return of capital and distributions to NRG, net of contributions	$	(2	)	$	65		$	(9	)

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

See accompanying notes to consolidated financial statements.

NRG YIELD LLC

CONSOLIDATED STATEMENTS OF MEMBERS' EQUITY



(In millions)	Contributed Capital			Retained Earnings			Accumulated Other Comprehensive Loss			Noncontrolling Interest			Total Members' Equity
Balances at December 31, 2014 ^(a)	$	2,308		$	133		$	(80	)	$	334		$	2,695
Members' equity - Acquired Drop Down Assets	208			(9		)	(2		)	(135		)	62
Balances at December 31, 2014	$	2,516		$	124		$	(82	)	$	199		$	2,757
Net income (loss) ^(b)	—			157			—			(62		)	95
Unrealized loss on derivatives	—			—			(16		)	(1		)	(17		)
Payment for January 2015 and November 2015 Drop Down Assets	(698		)	—			—			—			(698		)
Distributions and returns of capital to NRG, net of contributions ^(b)	(38		)	(41		)	—			—			(79		)
Capital contributions from NRG, non-cash ^(b)	(15		)	6			—			—			(9		)
Capital contributions from tax equity investors	—			—			—			122			122
Noncontrolling interest acquired in Spring Canyon acquisition	—			—			—			74			74
Proceeds from the issuance of Class C units	599			—			—			—			599
Distributions paid to NRG on Class B and Class D units	—			(70		)	—			—			(70		)
Distributions paid to Yield, Inc.	—			(69		)	—			—			(69		)
Balances at December 31, 2015	$	2,364		$	107		$	(98	)	$	332		$	2,705
Net income (loss) ^(b)	—			126			—			(111		)	15
Unrealized loss on derivatives	—			—			13			—			13
Payment for CVSR Drop Down Asset	(77		)	—			—			—			(77		)
Capital contributions from tax equity investors	—			—			—			5			5
Distributions paid to NRG, net of contributions ^(b)	(182		)	(2		)	—			—			(184		)
Distributions paid to NRG, net of contributions, non-cash^(b)	74			(9		)	—			—			65
Distributions paid to NRG on Class B and Class D units	—			(81		)	—			—			(81		)
Distributions paid to Yield, Inc., non-cash	—			(5		)	—			—			(5		)
Distributions paid to Yield, Inc.	—			(92		)	—			—			(92		)
Balances at December 31, 2016	$	2,179		$	44		$	(85	)	$	226		$	2,364
Net income (loss)	—			137			—			(75		)	62
Unrealized gain on derivatives	—			—			17			—			17
Payments for the March 2017, August 2017 and November 2017 Drop Down Assets	(250		)	—			—			—			(250		)
August 2017 Drop Down Assets contingent consideration	(8		)	—			—			—			(8		)
Capital contributions from tax equity investors, net of distributions	—			—			—			11			11
Proceeds from the issuance of Class C units	34			—			—			—			34
Distributions paid to NRG, net of contributions	(18		)	—			—			—			(18		)
Distributions paid to NRG, net of contributions, non-cash	(8		)	6			—			—			(2		)
Distributions paid to NRG on Class B and Class D units	(6		)	(88		)	—			—			(94		)
Distributions paid to Yield, Inc.	(26		)	(82		)	—			—			(108		)
Balances at December 31, 2017	$	1,897		$	17		$	(68	)	$	162		$	2,008

^(a) As previously reported in the Company's consolidated financial statements for the year ended December 31, 2016, included in the Company's May 9, 2017 Form 8-K.

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

See accompanying notes to consolidated financial statements.

NRG YIELD LLC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1 — Nature of Business

NRG Yield LLC, together with its consolidated subsidiaries, or the Company, is the primary vehicle through which NRG owns, operates and acquires contracted renewable and conventional generation and thermal infrastructure assets. NRG owns 100% of the Company's Class B units and Class D units and receives distributions through its ownership of these units. NRG Yield, Inc., or Yield, Inc., owns 100% of the Company's Class A units and Class C units. NRG Yield LLC, through its wholly owned subsidiary, NRG Yield Operating LLC, or Yield Operating LLC, holds a portfolio of renewable and conventional generation and thermal infrastructure assets, primarily located in the Northeast, Southwest, Midwest and California regions of the U.S.

Yield, Inc. closed its initial public offering of Class A common stock in July 2013, which was then followed by a Class A common stock offering in July 2014, a Recapitalization in May 2015, as described below, and a Class C common stock offering in June 2015.

Effective May 14, 2015, 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 Yield, Inc.'s outstanding Class A common stock and Class B common stock, respectively, through a stock split. The stock split is referred to as the Recapitalization. The Company also amended its operating agreement to reflect the Recapitalization. Effective May 14, 2015, each Class A unit of the Company was automatically reclassified into one Class A unit and one Class C unit and each Class B unit of the Company was automatically reclassified into one Class B unit and one Class D unit.

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

https://cdn.kscope.io/7099ca460dbfd235dcdf54b42d2e49c3-yieldorgpicturerevisedasof97.jpg

On July 12, 2017, NRG announced that it had adopted and initiated a three-year, three-part improvement plan, or the NRG Transformation Plan. As part of the NRG Transformation Plan, NRG announced that it is exploring strategic alternatives for its renewables platform and its interest in the Company. NRG, through its holdings of Class B common stock and Class D common stock, has a 55.1% voting interest in the Company and receives distributions from NRG Yield LLC through its ownership of Class B units and Class D units.

On February 6, 2018, Global Infrastructure Partners, or GIP, entered into a purchase and sale agreement with NRG, or the NRG Transaction, for the acquisition of NRG's full ownership interests in the Company and NRG's renewable development and operations platform. The NRG Transaction is subject to certain closing conditions, including customary legal and regulatory approvals. The Company expects the NRG Transaction to close in the second half of 2018. NRG is the Company's controlling stockholder and the Company has been highly dependent on NRG for, among other things, growth opportunities and management and administration services. See Part I, Item 1A, Risk Factors for risks related to the Strategic Sponsorship with GIP and the Company's relationship with NRG.

As of December 31, 2017, the Company's operating assets are comprised of the following projects:



Projects	Percentage Ownership		Net Capacity (MW) ^(a)	Offtake Counterparty	Expiration
Conventional
El Segundo	100	%	550	Southern California Edison	2023
GenConn Devon	50	%	95	Connecticut Light & Power	2040
GenConn Middletown	50	%	95	Connecticut Light & Power	2041
Marsh Landing	100	%	720	Pacific Gas and Electric	2023
Walnut Creek	100	%	485	Southern California Edison	2023
			1,945
Utility Scale Solar
Agua Caliente	16	%	46	Pacific Gas and Electric	2039
Alpine	100	%	66	Pacific Gas and Electric	2033
Avenal	50	%	23	Pacific Gas and Electric	2031
Avra Valley	100	%	26	Tucson Electric Power	2032
Blythe	100	%	21	Southern California Edison	2029
Borrego	100	%	26	San Diego Gas and Electric	2038
CVSR	100	%	250	Pacific Gas and Electric	2038
Desert Sunlight 250	25	%	63	Southern California Edison	2034
Desert Sunlight 300	25	%	75	Pacific Gas and Electric	2039
Kansas South	100	%	20	Pacific Gas and Electric	2033
Roadrunner	100	%	20	El Paso Electric	2031
TA High Desert	100	%	20	Southern California Edison	2033
Utah Solar Portfolio^(b)(e)	50	%	265	PacifiCorp	2036
			921
Distributed Solar
Apple I LLC Projects	100	%	9	Various	2032
AZ DG Solar Projects	100	%	5	Various	2025-2033
SPP Projects	100	%	25	Various	2026-2037
Other DG Projects	100	%	13	Various	2023-2039
			52
Wind
Alta I	100	%	150	Southern California Edison	2035
Alta II	100	%	150	Southern California Edison	2035
Alta III	100	%	150	Southern California Edison	2035
Alta IV	100	%	102	Southern California Edison	2035
Alta V	100	%	168	Southern California Edison	2035
Alta X^(b)	100	%	137	Southern California Edison	2038
Alta XI ^(b)	100	%	90	Southern California Edison	2038
Buffalo Bear	100	%	19	Western Farmers Electric Co-operative	2033



Projects	Percentage Ownership		Net Capacity (MW) ^(a)	Offtake Counterparty	Expiration
Crosswinds ^(b)(f)	99	%	21	Corn Belt Power Cooperative	2027
Elbow Creek ^(b)(f)	100	%	122	NRG Power Marketing LLC	2022
Elkhorn Ridge ^(b)(f)	66.7	%	54	Nebraska Public Power District	2029
Forward ^(b)(f)	100	%	29	Constellation NewEnergy, Inc.	2022
Goat Wind ^(b)(f)	100	%	150	Dow Pipeline Company	2025
Hardin ^(b)(f)	99	%	15	Interstate Power and Light Company	2027
Laredo Ridge	100	%	80	Nebraska Public Power District	2031
Lookout ^(b)(f)	100	%	38	Southern Maryland Electric Cooperative	2030
Odin ^(b)(f)	99.9	%	20	Missouri River Energy Services	2028
Pinnacle	100	%	55	Maryland Department of General Services and University System of Maryland	2031
San Juan Mesa ^(b)(f)	75	%	90	Southwestern Public Service Company	2025
Sleeping Bear ^(b)(f)	100	%	95	Public Service Company of Oklahoma	2032
South Trent	100	%	101	AEP Energy Partners	2029
Spanish Fork ^(b)(f)	100	%	19	PacifiCorp	2028
Spring Canyon II ^(b)	90.1	%	29	Platte River Power Authority	2039
Spring Canyon III ^(b)	90.1	%	25	Platte River Power Authority	2039
Taloga	100	%	130	Oklahoma Gas & Electric	2031
Wildorado ^(b)(f)	100	%	161	Southwestern Public Service Company	2027
			2,200
Thermal
NRG Energy Center Dover LLC	100	%	103	NRG Power Marketing LLC	2018
Thermal generation	100	%	20	Various	Various
			123
Total net generation capacity^(c)			5,241

Thermal equivalent MWt^(d)	100	%	1,319	Various	Various

^(a) Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of December 31, 2017.

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

^(c) The Company's total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. The Company's generation capacity including this noncontrolling interest was 5,247.

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

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

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

In addition to the facilities owned or leased in the table above, the Company entered into partnerships to own or purchase solar power generation projects, as well as other ancillary related assets from a related party via intermediate funds. The Company does not consolidate these partnerships and accounts for them as equity method investments. The Company's net interest in these projects is 247 MW based on cash to be distributed as of December 31, 2017. For further discussions, refer to Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities to the Consolidated Financial Statements.

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

As described in Note 13, Related Party Transactions to the Consolidated Financial Statements, the Company has a management services agreement with NRG for various services, including human resources, accounting, tax, legal, information systems, treasury, and risk management.

During the years ending December 31, 2017 and 2016 the Company completed four acquisitions of Drop Down Assets from NRG. The accounting guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect from the beginning of the financial statement period or from the date the entities were under common control (if later than the beginning of the financial statement period). For further discussion, see Note 3, Business Acquisitions to the Consolidated Financial Statements.

Note 2 — Summary of Significant Accounting Policies

Basis of Presentation and Principles of Consolidation

The Company's consolidated financial statements have been prepared in accordance with GAAP. The ASC is the source of authoritative GAAP to be applied by nongovernmental entities. In addition, the rules and interpretative releases of the SEC under authority of federal securities laws are also sources of authoritative GAAP for SEC registrants.

The consolidated financial statements include the Company's accounts and operations and those of its subsidiaries in which it has a controlling interest. All significant intercompany transactions and balances have been eliminated in consolidation. The usual condition for a controlling financial interest is ownership of a majority of the voting interests of an entity. However, a controlling financial interest may also exist through arrangements that do not involve controlling voting interests. As such, the Company applies the guidance of ASC 810, Consolidations, or ASC 810, to determine when an entity that is insufficiently capitalized or not controlled through its voting interests, referred to as a variable interest entity, or VIE, should be consolidated.

Cash and Cash Equivalents

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase. Cash and cash equivalents held at project subsidiaries was $124 million and $111 million as of December 31, 2017 and 2016, respectively.

Restricted Cash

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the consolidated balance sheets that sum to the total of the same such amounts shown in the statements of cash flows.



	Year Ended December 31,
	2017		2016		2015
	(In millions)
Cash and cash equivalents	$	146	$	321	$	110
Restricted cash	168		176		143
Cash, cash equivalents and restricted cash shown in the statement of cash flows	314		497		253

Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company's projects that are restricted in their use. Of these funds as of December 31, 2017, approximately $25 million is designated for current debt service payments, $25 million is designated to fund operating expenses and $36 million is designated for distributions to the Company, with the remaining $82 million restricted for reserves including debt service, performance obligations and other reserves, as well as capital expenditures.

Trade Receivables and Allowance for Doubtful Accounts

Trade receivables are reported on the balance sheet at the invoiced amount adjusted for any write-offs and the allowance for doubtful accounts. The allowance for doubtful accounts is reviewed periodically based on amounts past due and significance. The allowance for doubtful accounts was immaterial as of December 31, 2017 and 2016.

Inventory

Inventory consists principally of spare parts and fuel oil. Spare parts inventory is valued at weighted average cost, unless evidence indicates that the weighted average cost will not be recovered with a normal profit in the ordinary course of business. Fuel oil inventory is valued at the lower of weighted average cost or market. The Company removes fuel inventories as they are used in the production of steam, chilled water or electricity. Spare parts inventory are removed when they are used for repairs, maintenance or capital projects.

Property, Plant and Equipment

Property, plant and equipment are stated at cost or, in the case of third party business acquisitions, fair value; however impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying values may not be recoverable. See Note 3, Business Acquisitions, for more information on acquired property, plant and equipment. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation is computed using the straight-line method over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations. For further discussion of the Company's property, plant and equipment refer to Note 4, Property, Plant and Equipment to the Consolidated Financial Statements.

Asset Impairments

Long-lived assets that are held and used are reviewed for impairment whenever events or changes in circumstances indicate carrying values may not be recoverable. Such reviews are performed in accordance with ASC 360. An impairment loss is indicated if the total future estimated undiscounted cash flows expected from an asset are less than its carrying value. An impairment charge is measured by the difference between an asset's carrying amount and fair value with the difference recorded in operating costs and expenses in the statements of operations. Fair values are determined by a variety of valuation methods, including appraisals, sales prices of similar assets and present value techniques. For further discussion of the Company's long-lived asset impairments, refer to Note 9, Asset Impairments to the Consolidated Financial Statements.

Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures, which requires that a loss in value of an investment that is an other-than-temporary decline should be recognized. The Company identifies and measures losses in the value of equity method investments based upon a comparison of fair value to carrying value.

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis which approximates the effective interest method over the term of the related debt. Debt issuance costs related to the long term debt are presented as a direct deduction from the carrying amount of the related debt in both the current and prior periods. Debt issuance costs related to the senior secured revolving credit facility line of credit are recorded as a non-current asset on the balance sheet and are amortized over the term of the credit facility.

Intangible Assets

Intangible assets represent contractual rights held by the Company. The Company recognizes specifically identifiable intangible assets including power purchase agreements, leasehold improvements, customer relationships, customer contracts, and development rights when specific rights and contracts are acquired. These intangible assets are amortized primarily on a straight-line basis. For further discussion of the Company's intangible assets, refer to Note 8, Intangible Assets to the Consolidated Financial Statements.

Notes Receivable

Notes receivable consist of receivables related to the financing of required network upgrades. The notes issued with respect to network upgrades will be repaid within a 5-year period following the date each facility reached commercial operations.

Income Taxes

The Company is classified as a partnership for federal and state income tax purposes. Therefore, federal and state income taxes are assessed at the partner level. Accordingly, no provision has been made for federal or state income taxes in the accompanying financial statements.

Revenue Recognition

Thermal Revenues

Steam and chilled water revenue is recognized based on customer usage as determined by meter readings taken at month-end. Some locations read customer meters throughout the month, and recognize estimated revenue for the period between meter read date and month-end. The Thermal Business subsidiaries collect and remit state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes are presented on a net basis in the income statement.

Power Purchase Agreements, or PPAs

The majority of the Company’s revenues are obtained through PPAs or other contractual agreements, which are accounted for as operating leases under ASC 840. ASC 840 requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. Judgment is required by management in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or capital lease.

Certain of these leases have no minimum lease payments and all of the rental income under these leases is recorded as contingent rent on an actual basis when the electricity is delivered. The contingent rental income recognized in the years ended December 31, 2017, 2016 and 2015 was $559 million, $583 million and $443 million, respectively. These balances include intercompany revenue for Elbow Creek of $8 million for each of the years ended December 31, 2017 and 2016, as further discussed in Note 13 Related Party Transactions.

Derivative Financial Instruments

The Company accounts for derivative financial instruments under ASC 815, Derivatives and Hedging, or ASC 815, which requires the Company to record all derivatives on the balance sheet at fair value unless they qualify for a NPNS exception. Changes in the fair value of non-hedge derivatives are immediately recognized in earnings. Changes in the fair value of derivatives accounted for as hedges, if elected for hedge accounting, are either:


•	Recognized in earnings as an offset to the changes in the fair value of the related hedged assets, liabilities and firm commitments; or


•	Deferred and recorded as a component of accumulated OCI until the hedged transactions occur and are recognized in earnings.

The Company's primary derivative instruments are power purchase or sale contracts used to mitigate variability in earnings due to fluctuations in market prices, fuels purchase contracts used to control customer reimbursable fuel cost, and interest rate instruments used to mitigate variability in earnings due to fluctuations in interest rates. On an ongoing basis, the Company assesses the effectiveness of all derivatives that are designated as hedges for accounting purposes in order to determine that each derivative continues to be highly effective in offsetting changes in fair values or cash flows of hedged items. Internal analyses that measure the statistical correlation between the derivative and the associated hedged item determine the effectiveness of such a contract designated as a hedge. If it is determined that the derivative instrument is not highly effective as a hedge, hedge accounting will be discontinued prospectively. In this case, the gain or loss previously deferred in accumulated OCI would be frozen until the underlying hedged item is delivered unless the transaction being hedged is no longer probable of occurring in which case the amount in OCI would be immediately reclassified into earnings. If the derivative instrument is terminated, the effective portion of this derivative deferred in accumulated OCI will be frozen until the underlying hedged item is delivered.

Revenues and expenses on contracts that qualify for the NPNS exception are recognized when the underlying physical transaction is delivered. While these contracts are considered derivative financial instruments under ASC 815, they are not recorded at fair value, but on an accrual basis of accounting. If it is determined that a transaction designated as NPNS no longer meets the scope exception, the fair value of the related contract is recorded on the balance sheet and immediately recognized through earnings.

Concentrations of Credit Risk

Financial instruments which potentially subject the Company to concentrations of credit risk consist primarily of accounts receivable, notes receivable and derivative instruments, which are concentrated within entities engaged in the energy and financial industry. These industry concentrations may impact the overall exposure to credit risk, either positively or negatively, in that the customers may be similarly affected by changes in economic, industry or other conditions. In addition, many of the Company's projects have only one customer. However, the Company believes that the credit risk posed by industry concentration is offset by the diversification and creditworthiness of its customer base. See Note 6, Fair Value of Financial Instruments, for a further discussion of derivative concentrations and Note 12, Segment Reporting, for concentration of counterparties.

Fair Value of Financial Instruments

The carrying amount of cash and cash equivalents, restricted cash, accounts receivable, accounts receivable - affiliate, accounts payable, current portion of account payable - affiliate, and accrued expenses and other current liabilities approximate fair value because of the short-term maturity of these instruments. See Note 6, Fair Value of Financial Instruments, for a further discussion of fair value of financial instruments.

Asset Retirement Obligations

Asset retirement obligations, or AROs, are accounted for in accordance with ASC 410-20, Asset Retirement Obligations, or ASC 410-20. Retirement obligations associated with long-lived assets included within the scope of ASC 410-20 are those for which a legal obligation exists under enacted laws, statutes, and written or oral contracts, including obligations arising under the doctrine of promissory estoppel, and for which the timing and/or method of settlement may be conditional on a future event. ASC 410-20 requires an entity to recognize the fair value of a liability for an ARO in the period in which it is incurred and a reasonable estimate of fair value can be made.

Upon initial recognition of a liability for an ARO, the asset retirement cost is capitalized by increasing the carrying amount of the related long-lived asset by the same amount. Over time, the liability is accreted to its future value, while the capitalized cost is depreciated over the useful life of the related asset. The Company's AROs are primarily related to the future dismantlement of equipment on leased property and environmental obligations related to site closures and fuel storage facilities. The Company records AROs as part of other non-current liabilities on its balance sheet.

The following table represents the balance of ARO obligations as of December 31, 2017 and 2016, along with the additions and accretion related to the Company's ARO obligations for the year ended December 31, 2017:



	(In millions)
Balance as of December 31, 2016	$	49
Revisions in estimates for current obligations/Additions	2
Accretion — expense	4
Balance as of December 31, 2017	$	55

Guarantees

The Company enters into various contracts that include indemnification and guarantee provisions as a routine part of its business activities. Examples of these contracts include operation and maintenance agreements, service agreements, commercial sales arrangements and other types of contractual agreements with vendors and other third parties, as well as affiliates. These contracts generally indemnify the counterparty for tax, environmental liability, litigation and other matters, as well as breaches of representations, warranties and covenants set forth in these agreements. Because many of the guarantees and indemnities the Company issues to third parties and affiliates do not limit the amount or duration of its obligations to perform under them, there exists a risk that the Company may have obligations in excess of the amounts agreed upon in the contracts mentioned above. For those guarantees and indemnities that do not limit the liability exposure, the Company may not be able to estimate what the liability would be, until a claim is made for payment or performance, due to the contingent nature of these contracts.

Investments Accounted for by the Equity Method

The Company has investments in various energy projects accounted for by the equity method, several of which are VIEs, where the Company is not a primary beneficiary, as described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities. The equity method of accounting is applied to these investments in affiliates because the ownership structure prevents the Company from exercising a controlling influence over the operating and financial policies of the projects. Under this method, equity in pre-tax income or losses of the investments is reflected as equity in earnings of unconsolidated affiliates. Distributions from equity method investments that represent earnings on the Company's investment are included within cash flows from operating activities and distributions from equity method investments that represent a return of the Company's investment are included within cash flows from investing activities.

Sale Leaseback Arrangements

The Company is party to sale-leaseback arrangements that provide for the sale of certain assets to a third party and simultaneous leaseback to the Company. In accordance with ASC 840-40, Sale-Leaseback Transactions, if the seller-lessee retains, through the leaseback, substantially all of the benefits and risks incident to the ownership of the property sold, the sale-leaseback transaction is accounted for as a financing arrangement. An example of this type of continuing involvement would include an option to repurchase the assets or the buyer-lessor having the option to sell the assets back to the Company. This provision is included in most of the Company’s sale-leaseback arrangements. As such, the Company accounts for these arrangements as financings.

Under the financing method, the Company does not recognize as income any of the sale proceeds received from the lessor that contractually constitutes payment to acquire the assets subject to these arrangements. Instead, the sale proceeds received are accounted for as financing obligations and leaseback payments made by the Company are allocated between interest expense and a reduction to the financing obligation. Interest on the financing obligation is calculated using the Company’s incremental borrowing rate at the inception of the arrangement on the outstanding financing obligation. Judgment is required to determine the appropriate borrowing rate for the arrangement and in determining any gain or loss on the transaction that would be recorded either at the end of or over the lease term.

Business Combinations

The Company accounts for its business combinations in accordance with ASC 805, Business Combinations, or ASC 805. For third party acquisitions, ASC 805 requires an acquirer to recognize and measure in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at fair value at the acquisition date. It also recognizes and measures the goodwill acquired or a gain from a bargain purchase in the business combination and determines what information to disclose to enable users of an entity's financial statements to evaluate the nature and financial effects of the business combination. In addition, transaction costs are expensed as incurred. For acquisitions that relate to entities under common control, ASC 805 requires retrospective combination of the entities for all periods presented as if the combination has been in effect from the beginning of the financial statement period of from the date the entities were under common control (if later than the beginning of the financial statement period). The difference between the cash paid and historical value of the entities' equity is recorded as a distribution/contribution from/to NRG with the offset to contributed capital. Transaction costs are expensed as incurred.

Use of Estimates

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

In recording transactions and balances resulting from business operations, the Company uses estimates based on the best information available. Estimates are used for such items as plant depreciable lives, uncollectible accounts, environmental liabilities, acquisition accounting and legal costs incurred in connection with recorded loss contingencies, among others. In addition, estimates are used to test long-lived assets for impairment and to determine the fair value of impaired assets. As better information becomes available or actual amounts are determinable, the recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting 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 distributed solar energy systems under operating leases or PPAs 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 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.

Reclassifications

Certain prior year amounts have been reclassified for comparative purposes.

Recent Accounting Developments - Adopted in 2017

ASU 2017-12 — In August 2017, the FASB issued ASU No. 2017-12, Derivatives and Hedging (Topic 815), Targeted Improvements to Accounting for Hedging Activities, or ASU No. 2017-12. ASU No. 2017-12 amends ASU No. 2016-15. The amendments of ASU No. 2016-15 were issued to simplify the application of hedge accounting guidance and more closely aligning financial reporting for hedging relationships with economic results of an entity's risk management activities. The issues addressed by ASU No. 2017-12 include but are not limited to alignment of risk management activities and financial reporting, risk component hedging, accounting for the hedged item in fair value hedges of interest rate risk, recognition and presentation of the effects of hedging instruments, amounts excluded from the assessment of hedge effectiveness, and other simplifications of hedge accounting guidance. The amendments of ASU No. 2017-12 are effective for fiscal years beginning after December 15, 2018, and interim periods therein. Early adoption is permitted in any interim period and the effect of the adoption should be reflected as of the beginning of the fiscal year of adoption. The Company early adopted ASU No. 2017-12 during the fourth quarter 2017. The adoption of ASU No. 2017-12 did not have a material impact on our consolidated results of operations, cash flows, and statement of financial position.

ASU 2016-18 — In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 230), Restricted Cash, or ASU No. 2016-18. The amendments of ASU No. 2016-18 require an entity to include amounts generally described as restricted cash and restricted cash equivalents with cash and cash equivalents when reconciling the beginning of period and end of period total amounts on the statement of cash flows. The amendments of ASU No. 2016-18 are effective for annual reporting periods beginning after December 15, 2017, and interim periods within those annual periods. Early adoption is permitted and the adoption of ASU No. 2016-18 will be applied retrospectively. The Company early adopted ASU No. 2016-18 during the second quarter of 2017. Net cash flows used in investing activities for the year ended December 31, 2016 decreased by $33 million. The sum of Company's cash and cash equivalents and restricted cash reported within the consolidated balance sheet as of December 31, 2016 equals the beginning balances of cash, cash equivalents and restricted cash shown in the consolidated statement of cash flows for the year ended December 31, 2017. The sum of Company's cash and cash equivalents and restricted cash reported within the consolidated balance sheet as of December 31, 2017 equals to the ending balances of cash, cash equivalents and restricted cash shown in the consolidated statement of cash flows for the year ended December 31, 2017.

Recent Accounting Developments - Not Yet Adopted

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

ASU 2014-09 — In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), or Topic 606, which was further amended through various updates issued by the FASB thereafter. The amendments of ASU No. 2014-09 completed the joint effort between the FASB and the IASB, to develop a common revenue standard for GAAP and IFRS, and to improve financial reporting. The guidance under Topic 606 provides that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for the goods or services provided and establishes a five step model to be applied by an entity in evaluating its contracts with customers. The Company has elected the practical expedient available under Topic 606 for measuring progress toward complete satisfaction of a performance obligation and for disclosure requirements of remaining performance obligations. The practical expedient allows an entity to recognize revenue in the amount to which the entity has the right to invoice such that the entity has a right to the consideration in an amount that corresponds directly with the value to the customer for performance completed to date by the entity. The majority of the Company's revenues are obtained through PPAs, which are currently accounted for as operating leases. In connection with the implementation of Topic 842, as described above, the Company expects to elect certain of the practical expedients permitted, including the expedient that permits the Company to retain its existing lease assessment and classification. The Company adopted the standard effective January 1, 2018 under the modified retrospective transition method. As leases are excluded from the scope of Topic 606, the adoption of Topic 606 at the date of initial application will not have a material impact on the Company's financial statements. The adoption of Topic 606 also includes additional disclosure requirements beginning in the first quarter of 2018. As a significant portion of the Company's revenue is generated through operating leases, the majority of the new required disclosures will not be relevant or material to the Company.

Note 3 — Business Acquisitions

2017 Acquisitions

November 2017 Drop Down Assets — On November 1, 2017, the Company acquired a 38 MW solar portfolio primarily comprised of assets from NRG's Solar Power Partners (SPP) funds and other projects developed by NRG, for cash consideration of $74 million, including working capital adjustments of $3 million, plus assumed non-recourse debt of $26 million.

The purchase price for the November 2017 Drop Down Assets was funded with cash on hand. The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues. The difference between the cash paid and historical value of the entities' equity was recorded as a contribution from NRG and increased the balance of contributed capital. 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 following is a summary of assets and liabilities transferred in connection with the acquisition of the November 2017 Drop Down Assets as of November 1, 2017:



	(In millions)
Assets:
Current assets	$	7
Property, plant and equipment	83
Non-current assets	12
Total assets	102
Liabilities:
Debt (Current and non-current) ^(a)	23
Other current and non-current liabilities	3
Total liabilities assumed	26
Net assets acquired	$	76

^(a) Net of $3 million of net debt issuance costs.

Since the acquisition date, the November 2017 Drop Down Assets have contributed $1 million in operating revenues to the Company.

August 2017 Drop Down Assets — On August 1, 2017, the Company acquired the remaining 25% interest in NRG Wind TE Holdco, a portfolio of 12 wind projects, from NRG for total cash consideration of $44 million, including working capital adjustment of $3 million. The purchase agreement also included potential additional payments to NRG dependent upon actual

energy prices for merchant periods beginning in 2027, which were estimated and accrued as contingent consideration in the amount of $8 million as of September 30, 2017.

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

The Class A interests of NRG Wind TE Holdco are owned by a tax equity investor, or TE Investor, who receives 99% of allocations of taxable income and other items until the flip point, which occurs when the TE Investor obtains a specified return on its initial investment, at which time the allocations to the TE Investor change to 8.53%. The Company generally receives 100% of CAFD until the flip point, at which time the allocations to the Company of CAFD change to 91.47%. If the flip point has not occurred by a specified date, 100% of CAFD is allocated to the TE 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 tables present a summary of the Company's historical information combining the financial information for the November 2017 Drop Down Assets and August 2017 Drop Down Assets transferred in connection with the acquisitions:



	Year ended December 31, 2016									Year ended December 31, 2015
	As Previously Reported ^(a)		November 2017 Drop Down Assets		August 2017 Drop Down Assets			As Currently Reported		As Previously Reported ^(a)		November 2017 Drop Down Assets		August 2017 Drop Down Assets		As Currently Reported
(In millions)
Total operating revenues	$	1,021	$	14	$	—		$	1,035	$	953	$	15	$	—	$	968
Operating income	220		4		—			224		322		6		—		328
Net income	15		—		—			15		93		2		—		95
Net income attributable to Yield LLC	157		—		(31		)	126		144		3		10		157

^(a) As previously reported in the May 9, 2017 Form 8-K filed in connection with the March 2017 Drop Down completed on March 27, 2017



	As of December 31, 2016
(In millions)	As Previously Reported^(a)		November 2017 Drop Down Assets		As Currently Reported
Assets:
Current assets	$	656	$	14	$	670
Property, plant and equipment	5,460		94		5,554
Non-current assets	2,504		18		2,522
Total assets	8,620		126		8,746
Liabilities:
Debt (Current and non-current)	6,007		62		6,069
Other current and non-current liabilities	309		4		313
Total liabilities assumed	6,316		66		6,382
Net assets	$	2,304	$	60	$	8,746

^(a) As previously reported in the May 9, 2017 Form 8-K filed in connection with the March 2017 Drop Down completed on March 27, 2017.

March 2017 Drop Down Assets — On March 27, 2017, the Company acquired the following interests from NRG: (i) Agua Caliente Borrower 2 LLC, which owns a 16% interest (approximately 31% of NRG's 51% interest) in the Agua Caliente solar farm, one of the ROFO Assets, representing ownership of approximately 46 net MW of capacity and (ii) NRG's interests in the Utah Solar Portfolio. Agua Caliente is located in Yuma County, AZ and sells power subject to a 25-year PPA with Pacific Gas and Electric, with 22 years remaining on that contract. The seven utility-scale solar farms in the Utah Solar Portfolio are owned by the following entities: Four Brothers Capital, LLC, Iron Springs Capital, LLC, and Granite Mountain Capital, LLC. These utility-scale solar farms achieved commercial operations in 2016, sell power subject to 20-year PPAs with PacifiCorp, a subsidiary of Berkshire Hathaway and are part of a tax equity structure with Dominion Solar Projects III, Inc., or Dominion, through which the Company is entitled to receive 50% of cash to be distributed, as further described below. The Company paid cash consideration of $132 million, including $2 million of working capital. The acquisition of the March 2017 Drop Down Assets was funded with cash on hand. The Company recorded the acquired interests as equity method investments. The Company also assumed non-recourse debt of $41 million and $287 million on Agua Caliente Borrower 2 LLC and the Utah Solar Portfolio, respectively, as further described in Note 10, Long-term Debt, as well as its pro-rata share of non-recourse project-level debt of Agua Caliente Solar LLC.

The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combination - Related Issues. The difference between the cash paid and the historical value of the entities' equity of $8 million was recorded as an adjustment to NRG's noncontrolling interest. Since the transaction constituted a transfer of entities under common control, the accounting guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect from the beginning of the financial statement period or from the date the entities were under common control (if later than the beginning of the financial statement period). Accordingly, in connection with the retrospective adjustment of prior periods, the Company adjusted its financial statements to reflect its results of operations, financial position and cash flows as if it recorded its interests in the Agua Caliente Borrower 2 LLC on January 1, 2016, and its interests in the Utah Solar Portfolio on November 2, 2016.

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



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

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

2016 Acquisitions

CVSR Drop Down — Prior to September 1, 2016, the Company had a 48.95% interest in CVSR, which was accounted for as an equity method investment. On September 1, 2016, the Company acquired from NRG the remaining 51.05% interest of CVSR Holdco LLC, which indirectly owns the CVSR solar facility, or the CVSR Drop Down, for total cash consideration of $78.5 million, plus an immaterial working capital adjustment. The acquisition was funded with cash on hand. The Company also assumed additional debt of $496 million, which represents 51.05% of the CVSR project level debt and 51.05% of the notes issued under the CVSR Holdco Financing Agreement, as of the closing date. The acquisition was funded with cash on hand.

CVSR and 100% of its debt, consisting of $771 million of project level debt and $200 million of notes issued under the CVSR Holdco Financing Agreement as of September 1, 2016. In addition, the Company has removed the equity method investment from all prior periods and adjusted its financial statements to reflect its results of operations, financial position and cash flows as if it had consolidated CVSR from the beginning of the financial statement period.

2015 Acquisitions

November 2015 Drop Down Assets from NRG — On November 3, 2015, the Company acquired the November 2015 Drop Down Assets, a portfolio of 12 wind facilities totaling 814 net MW, from NRG for cash consideration of $207 million. The Company was responsible for its pro-rata share of non-recourse project debt of $193 million and noncontrolling interest associated with a tax equity structure of $159 million (as of the acquisition date).

The Company funded the acquisition with borrowings from 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. The difference between the cash paid and historical value of the entities' equity was recorded as a distribution from NRG with the offset to contributed capital.

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 32 MW wind facility, and Spring Canyon III, a 28 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, each 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-year 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 Putnam, 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. The difference between the cash paid and the historical value of the entities' equity of $61 million was recorded as a distribution to NRG and reduced the balance of its contributed capital.

Note 4 — Property, Plant and Equipment

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



	December 31, 2017			December 31, 2016			Depreciable Lives
	(In millions)
Facilities and equipment	$	6,289		$	6,339		2 - 45 Years
Land and improvements	166			167
Construction in progress ^(a)	34			24
Total property, plant and equipment	6,489			6,530
Accumulated depreciation	(1,285		)	(976		)
Net property, plant and equipment	$	5,204		$	5,554

^(a) As of December 31, 2017 and 2016, construction in progress includes $24 million and $20 million of capital expenditures that relate to prepaid long-term service agreements in the Conventional segment, respectively.

The Company recorded long-lived asset impairments during the years ended December 31, 2017 and 2016, as further described in Note 9, Asset Impairments.

Note 5 — Investments Accounted for by the Equity Method and Variable Interest Entities

Equity Method Investments

The following table summarizes the Company's equity method investments as of December 31, 2017:



Name	Economic Interest	Investment Balance
		(In millions)
Utah Solar Portfolio^(a)	50%	$345
Desert Sunlight	25%	272
GenConn^(b)	50%	102
Agua Caliente Borrower 2	16%	92
Elkhorn Ridge^(c)	66.7%	73
San Juan Mesa^(c)	75%	66
NRG DGPV Holdco 1 LLC ^(d)	95%	76
NRG DGPV Holdco 2 LLC ^(d)	95%	61
NRG DGPV Holdco 3 LLC ^(d)	99%	39
NRG RPV Holdco 1 LLC^(d)	95%	58
Avenal	50%	(6)
Total equity investments in affiliates		$1,178

^(a) Economic interest based on cash to be distributed. Four Brothers Solar, LLC, Granite Mountain Holdings, LLC and Iron Springs Holdings, LLC are tax equity structures and VIEs. The related allocations are described below.

^(b) GenConn is a variable interest entity.

^(c) San Juan Mesa and Elkhorn Ridge are part of the Wind TE Holdco tax equity structure, as described below. San Juan Mesa and Elkhorn Ridge are owned 75% and 66.7%, respectively, by Wind TE Holdco. The Company owns 100% of the Class B interests in Wind TE Holdco.

^(d) Economic interest based on cash to be distributed. NRG DGPV Holdco 1 LLC, NRG DGPV Holdco 2 LLC, NRG DGPV Holdco 3 LLC and NRG RPV Holdco 1 LLC are tax equity structures and VIEs. The related allocations are described below.

As of December 31, 2017 and 2016, the Company had $57 million and $51 million, respectively, of undistributed earnings from its equity method investments.

The Company acquired its interest in Desert Sunlight on June 30, 2015, for $285 million, which resulted in a difference between the purchase price and the basis of the acquired assets and liabilities of $171 million. The difference is attributable to the fair value of the property, plant and equipment and power purchase agreements. In addition, the difference between the basis of the acquired assets and liabilities and the purchase price for the Utah Solar Portfolio (Four Brothers Solar, LLC, Granite Mountain Holdings, LLC and Iron Springs Holdings, LLC) of $106 million is attributable to the fair value of the property, plant and equipment.

The Company is amortizing the related basis differences to equity in earnings (losses) over the related useful life of the underlying assets acquired.

Non-recourse project-level debt of unconsolidated affiliates

The Company's pro-rata share of non-recourse debt held by unconsolidated affiliates was $777 million as of December 31, 2017.

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



	Year Ended December 31,
	2017			2016				2015
Income Statement Data:	(In millions)
GenConn
Operating revenues	$	71		$	72			$	78
Operating income	36			38				40
Net income	26			26				28
Desert Sunlight
Operating revenues	207			211				206
Operating income	127			129				124
Net income	80			80				73
Utah Solar Portfolio ^(a)
Operating revenues	75			13				—
Operating income (loss)	18			(6		)		(1		)
Net income (loss)	18			(6		)		(1		)
DGPV entities ^(b)
Operating revenues	37			14				1
Operating income	7			2				—
Net loss	(3		)	—				—
RPV Holdco
Operating revenues	16			13				4
Operating income	3			2				(6		)
Net income (loss)	3			2				(6		)

				As of December 31,
				2017				2016
Balance Sheet Data:				(In millions)
GenConn
Current assets				$	38			$	36
Non-current assets				374				389
Current liabilities				18				16
Non-current liabilities				189				196
Desert Sunlight
Current assets				133				281
Non-current assets				1,350				1,401
Current liabilities				64				64
Non-current liabilities				1,003				1,043
Utah Solar Portfolio ^(a)
Current assets				13				20
Non-current assets				1,090				1,105
Current liabilities				5				14
Non-current liabilities				24				38
DGPV entities ^(b)
Current assets				74				44
Non-current assets				671				562
Current liabilities				83				112
Non-current liabilities				216				23
Redeemable Noncontrolling Interest				44				28
RPV Holdco
Current assets				3				15
Non-current assets				183				191
Current liabilities				—				11
Non-current liabilities				7				7
Redeemable Noncontrolling Interest				16			—	—

^(a) Utah Solar Portfolio was acquired by NRG on November 2, 2016.

^(b) Includes DGPV Holdco 1, DGPV Holdco 2 and DGPV Holdco 3

Variable Interest Entities, or VIEs

Entities that are Consolidated

NRG Wind TE Holdco — As described in Note 3, Business Acquisitions, on August 1, 2017, the Company acquired from NRG the remaining 25% interest in NRG Wind TE Holdco. 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 Class A interests of NRG Wind TE Holdco are owned by a tax equity investor, or TE Investor, who receives 99% of allocations of taxable income and other items until the flip point, which occurs when the TE Investor obtains a specified return on its initial investment, at which time the allocations to the TE Investor change to 8.53%. The Company generally receives 100% of CAFD until the flip point, at which time the allocations to the Company of CAFD change to 91.47%. If the flip point has not occurred by a specified date, 100% of CAFD is allocated to the TE Investor until the flip point occurs. The Company utilizes the HLBV method to determine the net income or loss allocated to the TE Investor noncontrolling interest.

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 PTCs. The financial institution, or Alta Investor, receives 99% of allocations of taxable income and other items until the flip point, which occurs when the Alta Investor obtains a specified return on its initial investment, at which time the allocations to the Alta Investor change to 5%. The Company receives 94.34% until the flip point, at which time the allocations to the Company of CAFD will change to 97.12%, unless the flip point will not have occurred by a specified date, which would result in 100% of CAFD allocated to the Alta 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, with the Alta Investor's interest shown as noncontrolling interest. The Company utilizes the HLBV method to determine the net income or loss allocated to the noncontrolling interest.

Spring Canyon — The Company holds a 90.1% of the Class B interests in Spring Canyon II, a 32 MW wind facility, and Spring Canyon III, a 28 MW wind facility, each located in Logan County, Colorado, and Invenergy Wind Global LLC owns 9.9% of the Class B interests. The projects are financed with a partnership flip tax-equity structure with a financial institution, who owns the Class A interests, to monetize certain cash and tax attributes, primarily PTCs. Until the flip point, the Class A member receives a variable percentage of cash distributions based on the projects’ production level during the prior year. The Class A member received 34.81% of the cash distributions and the Company and Invenergy received 65.19% during the period ended December 31, 2017. After the flip point, cash distributions are allocated 5% to the Class A member and 95% to the Company and Invenergy. Spring Canyon is a VIE and the Company is the primary beneficiary through its position as managing member, and therefore consolidates Spring Canyon. The Class A member and Invenergy's interests are shown as noncontrolling interest. The Company utilizes the HLBV method to determine the net income or loss allocated to the Class A member. Net income or loss attributable to the Class B interests is allocated to Invenergy's noncontrolling interest based on its 9.9% ownership interest.

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



(In millions)	NRG Wind TE Holdco		Alta TE Holdco		Spring Canyon
Other current and non-current assets	$	172	$	17	$	2
Property, plant and equipment	376		436		95
Intangible assets	2		262		—
Total assets	550		715		97
Current and non-current liabilities	197		9		5
Total liabilities	197		9		5
Noncontrolling interest	9		93		60
Net assets less noncontrolling interests	$	344	$	613	$	32

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.

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

NRG DGPV Holdco 1 LLC — The Company and NRG are parties to the NRG DGPV Holdco 1 LLC partnership, or DGPV Holdco 1, the purpose of which is to own or purchase solar power generation projects and other ancillary related assets from NRG Renew LLC or its subsidiaries via intermediate funds. The Company owns approximately 47 MW of distributed solar capacity, based on cash to be distributed, with a weighted average contract life of 18 years. Under this partnership, the Company committed to fund up to $100 million of capital.

NRG DGPV Holdco 2 LLC — The Company and NRG are parties to the NRG DGPV Holdco 2 LLC partnership, or DGPV Holdco 2, the purpose of which is to own or hold solar power generation projects as well as other ancillary related assets from NRG Renew LLC or its subsidiaries. The Company owns approximately 113 MW of distributed solar capacity, based on cash to be distributed, with a weighted average contract life of 21 years. Under this partnership, the Company committed to fund up to $60 million of capital.

NRG DGPV Holdco 3 LLC — On September 26, 2017, the Company entered into an additional partnership with NRG by forming NRG DGPV Holdco 3 LLC, or DGPV Holdco 3, in which the Company would invest up to $50 million in an operating portfolio of distributed solar assets, primarily comprised of community solar projects, developed by NRG. The Company owns approximately 43 MW of distributed solar capacity, based on cash to be distributed, with a weighted average contract life of approximately 20 years as of December 31, 2017.

The Company's maximum exposure to loss is limited to its equity investment in DGPV Holdco 1, DGPV Holdco 2 and DGPV Holdco 3, which was $176 million on a combined basis.

NRG RPV Holdco 1 LLC — The Company and NRG are parties to the NRG RPV Holdco 1 LLC partnership, or RPV Holdco, the purpose of which is to hold operating portfolios of residential solar assets developed by NRG's residential solar business, including: (i) an existing, unlevered portfolio of over 2,200 leases across nine states representing approximately 14 MW, based on cash to be distributed, with a weighted average remaining lease term of approximately 15 years that was acquired outside of the partnership; and (ii) a tax equity-financed portfolio of approximately 5,400 leases representing approximately 30 MW, based on cash to be distributed, with a weighted average remaining lease term for the existing and new leases of approximately 18 years. The Company has fully funded the partnership as of December 31, 2017.

The Company's maximum exposure to loss is limited to its equity investment, which was $58 million as of December 31, 2017.

Note 6 — Fair Value of Financial Instruments

For cash and cash equivalents, restricted cash, accounts receivable — affiliate, accounts receivable, accounts payable, current portion of accounts payable — affiliate, accrued expenses and other liabilities, the carrying amount approximates 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 December 31, 2017				As of December 31, 2016
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(In millions)
Assets:
Notes receivable, including current portion	$	13	$	13	$	30	$	30
Liabilities:
Long-term debt, including current portion — affiliate	618		618		618		608
Long-term debt, including current portion — external	$	5,281	$	5,297	$	5,516	$	5,500

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.

The fair value of the Company's publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of debt securities, non-publicly traded long-term debt, affiliate debt and certain notes receivable of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy. The following table presents the level within the fair value hierarchy for long-term debt, including current portion as of December 31, 2017 and 2016:



	As of December 31, 2017				As of December 31, 2016
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	870	$	5,045	$	833	$	5,275

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 December 31, 2017			As of December 31, 2016
		Fair Value ^(a)		Fair Value ^(a)		Fair Value ^(a)
(In millions)		Level 2		Level 1		Level 2
Derivative assets:
Commodity contracts		$	1	$	1	$	1
Interest rate contracts		1		—		1
Total assets		$	2	1		2
Derivative liabilities:
Commodity contracts		$	1	—		1
Interest rate contracts		47		—		78
Total liabilities		$	48	$	—	$	79

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

Derivative Fair Value Measurements

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

The fair value of each contract is discounted using a risk free interest rate. In addition, a credit reserve is applied to reflect credit risk, which for interest rate swaps, is calculated based on credit default swaps utilizing the bilateral method. For commodities, to the extent that NRG's net exposure under a specific master agreement is an asset, the Company uses the counterparty's default swap rate. If the exposure under a specific master agreement is a liability, the Company uses NRG's default swap rate. For interest rate swaps and commodities, the credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of December 31, 2017, the credit reserve resulted in a $1 million increase in fair value in interest expense. It is possible that future market prices could vary from those used in recording assets and liabilities and such variations could be material.

Concentration of Credit Risk

In addition to the credit risk discussion as disclosed in Note 2, Summary of Significant Accounting Policies, 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 December 31, 2017, credit risk exposure to these counterparties attributable to the Company's ownership interests was approximately $2.7 billion for the next five years. The majority of these power contracts are with utilities with strong credit quality and public utility commission or other regulatory support. However, such regulated utility counterparties can be impacted by changes in government regulations, which the Company is unable to predict.

Note 7 — Accounting for Derivative Instruments and Hedging Activities

ASC 815 requires the Company to recognize all derivative instruments on the balance sheet as either assets or liabilities and to measure them at fair value each reporting period unless they qualify for a NPNS exception. The Company may elect to designate certain derivatives as cash flow hedges, if certain conditions are met, and defer the change in fair value of the derivatives to accumulated OCI/OCL, until the hedged transactions occur and are recognized in earnings. For derivatives that are not designated as cash flow hedges or do not qualify for hedge accounting treatment, the changes in the fair value will be immediately recognized in earnings. Certain derivative instruments may qualify for the NPNS exception and are therefore exempt from fair value accounting treatment. ASC 815 applies to the Company's energy related commodity contracts and interest rate swaps.

Energy-Related Commodities

To manage the commodity price risk associated with its competitive supply activities and the price risk associated with wholesale power sales, the Company may enter into derivative hedging instruments, namely, forward contracts that commit the Company to sell energy commodities or purchase fuels/electricity in the future. The objectives for entering into derivatives contracts designated as hedges include fixing the price for a portion of anticipated future electricity sales and fixing the price of a portion of anticipated fuel/electricity purchases for the operation of its subsidiaries. As of December 31, 2017, the Company had forward contracts for the purchase of fuel commodities relating to the forecasted usage of the Company’s district energy centers extending through 2020 and electricity contracts to supply retail power to the Company's district energy centers extending through 2020. At December 31, 2017, these contracts were not designated as cash flow or fair value hedges.

Also, as of December 31, 2017, the Company had other energy-related contracts that did not meet the definition of a derivative instrument or qualified for the NPNS exception and were therefore exempt from fair value accounting treatment as follows:


•	Power tolling contracts through 2039, and


•	Natural gas transportation contracts through 2028.

Interest Rate Swaps

The Company is exposed to changes in interest rates through the issuance of variable rate debt. In order to manage interest rate risk, it enters into interest rate swap agreements.

As of December 31, 2017, the Company had interest rate derivative instruments on non-recourse debt extending through 2036, a portion 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 December 31, 2017 and 2016:



		Total Volume
		December 31, 2017		December 31, 2016
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		3
Interest	Dollars	$	1,940	$	2,090

Fair Value of Derivative Instruments

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



	Fair Value
	Derivative Assets ^(a)				Derivative Liabilities
	December 31, 2017		December 31, 2016		December 31, 2017		December 31, 2016
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current	$	—	$	—	$	4	$	26
Interest rate contracts long-term	1		1		9		39
Total Derivatives Designated as Cash Flow Hedges	1		1		13		65
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current	—		—		12		6
Interest rate contracts long-term	—		—		22		7
Commodity contracts current	1		2		1		1
Total Derivatives Not Designated as Cash Flow Hedges	1		2		35		14
Total Derivatives	$	2	$	3	$	48	$	79

^(a) Derivative Asset balances classified as current are included within the prepayments and other current assets line item of the Consolidated Balance Sheet. Derivative Asset balances classified as long-term are included within the other non-current assets line item of the Consolidated Balance Sheet.

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



	Gross Amounts Not Offset in the Statement of Financial Position
As of December 31, 2017	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	1		$	—		$	1
Derivative liabilities	(1		)	—			(1		)
Total commodity contracts	—			—			—
Interest rate contracts:
Derivative assets	1			(1		)	—
Derivative liabilities	(47		)	1			(46		)
Total interest rate contracts	(46		)	—			(46		)
Total derivative instruments	$	(46	)	$	—		$	(46	)



	Gross Amounts Not Offset in the Statement of Financial Position
As of December 31, 2016	Gross Amounts of Recognized Assets/Liabilities			Derivative Instruments			Net Amount
Commodity contracts:	(In millions)
Derivative assets	$	2		$	—		$	2
Derivative liabilities	(1		)	—			(1		)
Total commodity contracts	1			—			1
Interest rate contracts:
Derivative assets	1			(1		)	—
Derivative liabilities	(78		)	1			(77		)
Total interest rate contracts	(77		)	—			(77		)
Total derivative instruments	$	(76	)	$	—		$	(76	)

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:



	Year ended December 31,
	2017			2016			2015
	(In millions)
Accumulated OCL beginning balance	$	(86	)	$	(99	)	$	(82	)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	17			17			17
Mark-to-market of cash flow hedge accounting contracts	—			(4		)	(34		)
Accumulated OCL ending balance	(69		)	(86		)	(99		)
Accumulated OCL attributable to noncontrolling interests	(1		)	(1		)	(1		)
Accumulated OCL attributable to NRG Yield LLC	$	(68	)	$	(85	)	$	(98	)
Losses expected to be realized from OCL during the next 12 months	$	15

Amounts reclassified from accumulated OCL into income are recorded to interest expense.

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

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

Impact of Derivative Instruments on the Statements of Income

The Company has interest rate derivative instruments that are not designated as cash flow hedges. The effect of interest rate hedges is recorded to interest expense. For the years ended December 31, 2017, 2016 and 2015 the impact to the consolidated statements of income was a gain of $7 million, loss of $2 million and a gain of $17 million, respectively.

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

In 2015, commodity contracts also hedged the forecasted sale of power for the Elbow Creek until the start of the PPA with NRG Power Marketing LLC, or Power Marketing, with effective date of November 1, 2015. The effect of these commodity hedges was recorded to operating revenues. For the year ended December 31, 2015, the impact to the consolidated statements of income was an unrealized loss of $2 million.

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

Note 8 — Intangible Assets

Intangible Assets — The Company's intangible assets as of December 31, 2017 and 2016 primarily reflect intangible assets established from its business acquisitions and are comprised of the following:


•	PPAs — Established predominantly with the acquisitions of the Alta Wind Portfolio, Walnut Creek, Tapestry and Laredo Ridge, these represent the fair value of the PPAs acquired. These are amortized, generally on a straight-line basis, over the term of the PPA.


•	Leasehold Rights — Established with the acquisition of the Alta Wind Portfolio, this represents the fair value of contractual rights to receive royalty payments equal to a percentage of PPA revenue from certain projects. These are amortized on a straight-line basis.


•	Customer relationships — Established with the acquisition of NRG Energy Center Phoenix and NRG Energy Center

Omaha, these intangibles represent the fair value at the acquisition date of the businesses' customer base. The customer relationships are amortized to depreciation and amortization expense based on the expected discounted future net cash flows by year.


•	Customer contracts — Established with the acquisition of NRG Energy Center Phoenix, these intangibles represent the fair value at the acquisition date of contracts that primarily provide chilled water, steam and electricity to its customers. These contracts are amortized to revenues based on expected volumes.


•	Emission Allowances — These intangibles primarily consist of SO₂ and NOx emission allowances established with the El Segundo and Walnut Creek acquisitions. These emission allowances are held-for-use and are amortized to cost of operations, with NOx allowances amortized on a straight-line basis and SO₂ allowances amortized based on units of production.


•	Development rights — Arising primarily from the acquisition of solar businesses in 2010 and 2011, these intangibles are amortized to depreciation and amortization expense on a straight-line basis over the estimated life of the related project portfolio.


•	Other — Consists primarily of the acquisition date fair value of the contractual rights to a ground lease for South Trent and to utilize certain interconnection facilities for Blythe, as well as land rights acquired in connection with the acquisition of Elbow Creek.

The following tables summarize the components of intangible assets subject to amortization:



Year ended December 31, 2017	PPAs			Leasehold Rights			Customer Relationships			Customer Contracts			Emission Allowances			Development Rights			Other			Total
(In millions)
January 1, 2017	$	1,286		$	86		$	66		$	15		$	9		$	3		$	6		$	1,471
Asset impairments^(a)	(6		)	—			—			—			—			—			—			(6		)
December 31, 2017	1,280			86			66			15			9			3			6			1,465
Less accumulated amortization	(205		)	(13		)	(5		)	(8		)	(3		)	(1		)	(2		)	(237		)
Net carrying amount	$	1,075		$	73		$	61		$	7		$	6		$	2		$	4		$	1,228

^(a) $6 million of asset impairments relate to one of the November 2017 Drop Down Assets that was recorded by NRG during the quarter ended September 30, 2017, as further described in Note 9, Asset Impairments.



Year ended December 31, 2016	PPAs			Leasehold Rights			Customer Relationships			Customer Contracts			Emission Allowances			Development Rights			Other			Total
(In millions)
January 1, 2016	$	1,286		$	86		$	66		$	15		$	15		$	3		$	6		$	1,477
Other	—			—			—			—			(6		)	—			—			(6		)
December 31, 2016	1,286			86			66			15			9			3			6			1,471
Less accumulated amortization	(143		)	(9		)	(4		)	(7		)	(2		)	(1		)	(2		)	(168		)
Net carrying amount	$	1,143		$	77		$	62		$	8		$	7		$	2		$	4		$	1,303

The Company recorded amortization expense of $71 million during each of years ended December 31, 2017 and 2016, and $56 million during the year ended December 31, 2015. Of these amounts, $70 million for each of the years ended December 31, 2017 and 2016, and $55 million for the year ended December 31, 2015, were recorded to contract amortization expense and reduced operating revenues in the consolidated statements of operations. The Company estimates the future amortization expense for its intangibles to be $71 million for the next five years through 2022.

Out-of-market contracts — The out-of-market contract liability represents the out-of-market value of the PPAs for the Blythe solar project and Spring Canyon wind projects and the out-of-market value of the land lease for Alta Wind XI, LLC, as of their respective acquisition dates. The Blythe solar project's liability of $7 million was recorded to other non-current liabilities on the consolidated balance sheet and is amortized to revenue in the consolidated statements of income on a units-of-production basis over the twenty-year term of the agreement. Spring Canyon's liability of $3 million was recorded to other non-current liabilities and is amortized to revenue on a straight-line basis over the twenty-five year term of the agreement. The Alta Wind XI, LLC's liability of $5 million was recorded to other non-current liabilities and is amortized as a reduction to cost of operations on a straight-line basis over the thirty-four year term of the land lease. At December 31, 2017, accumulated amortization of out-of-market contracts was $4 million and amortization expense was $1 million for each of the years ended December 31, 2017 and 2016.

Note 9 — Asset Impairments

During the quarter ended December 31, 2017, as the Company updated its estimated cash flows in connection with the preparation and review of the Company's annual budget, the Company determined that the cash flows for Elbow Creek, located in Texas, and the Forward project, located in Pennsylvania, were below the carrying value of the related assets, primarily driven by continued declining merchant power prices in post-contract periods, and that the assets were considered impaired. The fair value of the facilities was determined using an income approach by applying a discounted cash flow methodology to the long-term budgets for each respective plant. The income approach utilized estimates of discounted future cash flows, which were Level 3 fair value measurement and include key inputs, such as forecasted power prices, operations and maintenance expense, and discount rates. The Company measured the impairment loss as the difference between the carrying amount and the fair value of the assets and recorded impairment losses of $26 million and $5 million for Elbow Creek and Forward, respectively.

Additionally, during the quarter ended September 30, 2017, in connection with the preparation of the model for sale of the November 2017 Drop Down Assets, it was identified that undiscounted cash flows were lower than the book value of certain SPP funds and NRG recorded an impairment expense of $13 million, $8 million of which relates to property, plant, and equipment and $5 million to PPAs, as described in Note 8, Intangible Assets. In accordance with the guidance for transfer of assets under common control, the impairment is reflected in the Company's consolidated statements of operations for the period ended December 31, 2017.

During the fourth quarter of 2016, as the Company updated its estimated cash flows in connection with the preparation and review of the Company's annual budget, the Company determined that the cash flows for the Elbow Creek and Goat Wind projects and the Forward project were below the carrying value of the related assets, primarily driven by declining merchant power prices in post-contract periods, and that the assets were considered impaired. These projects were acquired in connection with the acquisition of the November 2015 Drop Down Assets and were recorded as part of the Renewables segment of the Company. The projects were recorded at historical cost at acquisition date as they were related to interests under common control by NRG. The fair value of the facilities was determined using an income approach by applying a discounted cash flow methodology to the long-term budgets for each respective plant. The income approach utilized estimates of discounted future cash flows, which were Level 3 fair value measurement and include key inputs, such as forecasted power prices, operations and maintenance expense, and discount rates. The Company measured the impairment loss as the difference between the carrying amount and the fair value of the assets and recorded impairment losses of $117 million, $60 million and $6 million for Elbow Creek, Goat Wind, and Forward, respectively.

Other Impairments — During the fourth quarters of 2016 and 2015, NRG recorded impairment losses of approximately $2 million and $1 million, respectively, related to the projects that were part of the November 2017 Drop Down Assets. Since the acquisition by the Company of the November 2017 Drop Down Assets related to transfer of assets under common control, these impairments were reflected in the Company's consolidated statements of operations for the periods ending December 31, 2016 and 2015.

Note 10 — Long-term Debt

The Company's borrowings, including short term and long term portions consisted of the following:



	December 31, 2017			December 31, 2016			Interest rate % ^(a)	Letters of Credit Outstanding at December 31, 2017
	(In millions, except rates)
2026 Senior Notes	$	350		$	350		5.000
2024 Senior Notes	500			500			5.375
Long-term debt - affiliate, due 2020	281			281			3.325
Long-term debt - affiliate, due 2019	337			337			3.580
NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, due 2019 ^(b)	55			—			L+2.500	74
Project-level debt:
Agua Caliente Borrower 2, due 2038	41			—			5.430	17
Alpine, due 2022	135			145			L+1.750	16
Alta Wind I - V lease financing arrangements, due 2034 and 2035	926			965			5.696 - 7.015	119
CVSR, due 2037	746			771			2.339 - 3.775	—
CVSR Holdco Notes, due 2037	194			199			4.680	13
El Segundo Energy Center, due 2023	400			443			L+1.75 - L+2.375	102
Energy Center Minneapolis, due 2025	83			96			5.950	—
Energy Center Minneapolis Series D Notes, due 2031	125			125			3.550	—
Laredo Ridge, due 2028	95			100			L+1.875	10
Marsh Landing, due 2023	318			370			L+1.875	22
Tapestry, due 2021	162			172			L+1.625	20
Utah Solar Portfolio, due 2022	278			287			various	13
Viento, due 2023	163			178			L+3.00	27
Walnut Creek, due 2023	267			310			L+1.625	41
Other	443			505			various	38
Subtotal project-level debt	4,376			4,666
Total debt	5,899			6,134
Less current maturities	(306		)	(323		)
Less net debt issuance costs	(54		)	(65		)
Total long-term debt	$	5,539		$	5,746

^(a) As of December 31, 2017, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023, where L + equals 6 month LIBOR plus 3.00%.

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

The financing arrangements listed above contain certain covenants, including financial covenants, that the Company is required to be in compliance with during the term of the respective arrangement. As of December 31, 2017, the Company was in compliance with all of the required covenants.

NRG Yield Operating LLC 2026 Senior Notes

On August 18, 2016, Yield Operating LLC issued $350 million of senior unsecured notes, or the 2026 Senior Notes. The 2026 Senior Notes bear interest at 5.00% and mature on September 15, 2026. Interest on the notes is payable semi-annually on March 15 and September 15 of each year. The 2026 Senior Notes are senior unsecured obligations of Yield Operating LLC and are guaranteed by the Company, and by certain of Yield Operating LLC's wholly owned current and future subsidiaries. A portion of the proceeds of the 2026 Senior Notes were used to repay the Company's revolving credit facility during 2016, as described below.

Yield, Inc. 2020 Convertible Senior Notes and Related Intercompany Note

On June 29, 2015, Yield, Inc. closed on its offering of $288 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 Yield, Inc.'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 a conversion rate of approximately 36.3636 shares of Class C common stock per $1,000 principal amount of 2020 Convertible Notes. The Company and Yield Operating LLC provided a guarantee to Yield, Inc. with respect to the 2020 Convertible Notes. In addition, Yield Operating LLC and Yield, Inc. entered into an intercompany borrowing arrangement, under which Yield Operating LLC received $281 million of the proceeds of the 2020 Convertible Notes. The intercompany note bears interest at a rate of 3.325% and matures in 2020.

Yield, Inc. 2019 Convertible Senior Notes and Related Intercompany Note

During the first quarter of 2014, Yield, Inc. closed on its offering of $345 million aggregate principal amount of 3.50% Convertible Senior Notes due 2019, or the 2019 Convertible Notes. The 2019 Convertible Notes were convertible, under certain circumstances, into Yield, Inc.’s Class A common stock, cash or a combination thereof at an initial conversion price of $46.55 per Class A common share, which is equivalent to a conversion rate of approximately 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. The Company and Yield Operating LLC provided a guarantee to Yield, Inc. with respect to the 2019 Convertible Notes. In addition, Yield Operating and Yield, Inc. entered into an intercompany borrowing arrangement, under which Yield Operating borrowed $337 million of the proceeds of the 2019 Convertible Notes. The intercompany note bears interest at a rate of 3.580% and matures in 2019.

NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility

The Company borrowed $55 million from the revolving credit facility during the year ended December 31, 2017 for general corporate needs as well as to fund dividend payments.

The Company used its proceeds of $97.5 million from the CVSR Holdco Financing Arrangement, a portion of its proceeds from the issuance of the 2026 Senior Notes, as well as its cash on hand to repay the outstanding borrowings under the revolving credit facility during the year ended December 31, 2016.

On February 6, 2018, NRG Yield Operating LLC and NRG Yield LLC amended the revolving credit facility to modify the "change of control" provisions to permit the consummation of the NRG Transaction, and also to permit NRG Yield Operating LLC, NRG Yield LLC and certain subsidiaries to incur up to $1.5 billion of unsecured indebtedness in order to repurchase or make other required cash payments, in each case if applicable, with respect to NRG Yield Operating LLC’s outstanding senior notes and NRG Yield's outstanding convertible notes in connection with the NRG Transaction.

Project - level Debt

November 2017 Drop Down Assets Debt

As part of the November 2017 Drop Down acquisition, the Company assumed non-recourse debt of $26 million relating to certain SPP funds. The assumed debt consisted of the following: a) a term loan under a credit agreement with a bank, with a maturity date of December 31, 2038 and interest rate of 4.69%. The credit agreement includes a letter of credit supporting debt service requirements and a letter of credit in support of the PPA; b) and financing obligation in connection with a sale-leaseback transaction with a bank for a period through March 31, 2032. The company will accrete the financing obligation over the lease term based on the lease's implicit interest rate of 8%.

Agua Caliente Borrower 2, due 2038

On February 17, 2017, Agua Caliente Borrower 1 LLC, an indirect subsidiary of NRG, and Agua Caliente Borrower 2 LLC, issued $130 million of senior secured notes under the Agua Caliente Borrower 1 LLC and Agua Caliente Borrower 2 LLC financing agreement, or Agua Caliente Holdco Financing Agreement, that bear interest at 5.43% and mature on December 31, 2038. As described in Note 3, Business Acquisitions, on March 27, 2017, the Company acquired Agua Caliente Borrower 2 LLC from NRG as part of the March 2017 Drop Down Assets acquisition and assumed NRG's portion of senior secured notes under the Agua Caliente Holdco Financing Agreement. Agua Caliente Borrower 2 LLC holds $41 million of the Agua Caliente Holdco debt as of December 31, 2017. The debt is joint and several with respect to Agua Caliente Borrower 1 LLC and Agua Caliente Borrower 2 LLC and is secured by the equity interests of each borrower in the Agua Caliente solar facility.

Utah Solar Portfolio, due 2022

As part of the March 2017 Drop Down Assets acquisition, the Company assumed non-recourse debt of $287 million relating to the Utah Solar Portfolio at an interest rate of LIBOR plus 2.625%. The debt matures on December 16, 2022. The $287 million consisted of $222 million outstanding at the time of NRG's acquisition of the Utah Solar Portfolio on November 2, 2016, and additional borrowings of $65 million, net of debt issuance costs, incurred during 2016. The Company holds $278 million of the Utah Solar Portfolio debt as of December 31, 2017.

Thermal Financing

On October 31, 2016, NRG Energy Center Minneapolis LLC, a subsidiary of the Company, received proceeds of $125 million from the issuance of 3.55% Series D notes due October 31, 2031, or the Series D Notes, and entered into a shelf facility for the anticipated issuance of an additional $70 million of Series E notes at a 4.80% fixed rate. The Series D Notes will be secured by substantially all of the assets of NRG Energy Center Minneapolis LLC. NRG Thermal LLC has guaranteed the indebtedness and its guarantee is secured by a pledge of the equity interests in all of NRG Thermal LLC’s subsidiaries. NRG Energy Center Minneapolis LLC distributed the proceeds of the Series D Notes to NRG Thermal LLC, which in turn distributed the proceeds to NRG Yield Operating LLC to be utilized for general corporate purposes, including potential acquisitions.

On March 16, 2017, NRG Energy Center Minneapolis LLC, a subsidiary of NRG Thermal LLC, amended the shelf facility of its existing Thermal financing arrangement to allow for the issuance of an additional $10 million of Series F notes at a 4.60% interest rate, or Series F Notes, increasing the total principal amount of notes available for issuance under the shelf facility to $80 million. The Series E and Series F Notes will be secured by substantially all of the assets of NRG Energy Center Minneapolis LLC. NRG Thermal LLC has guaranteed the indebtedness and its guarantee is secured by a pledge of the equity interests in all of NRG Thermal LLC’s subsidiaries.

CVSR Holdco Notes, due 2037

On July 15, 2016, CVSR Holdco, the indirect owner of the CVSR solar facility, issued $200 million of senior secured notes under the CVSR Holdco Financing Agreement, or 2037 CVSR Holdco Notes, that bear interest at 4.68% and mature on March 31, 2037. Net proceeds were distributed to the Company and NRG based on their respective ownership as of July 15, 2016, and, accordingly, the Company received net proceeds of $97.5 million.

As described in Note 3, Business Acquisitions, on September 1, 2016, the Company acquired the remaining 51.05% of CVSR, and assumed additional debt of $496 million, which represents 51.05% of the CVSR project level debt and 51.05% of the 2037 CVSR Holdco Notes. In connection with the retrospective adjustment of prior periods, as described in Note 1, Nature of Business, the Company now consolidates CVSR and 100% of its debt, consisting of $771 million of project level debt and $200 million of 2037 CVSR Holdco Notes as of September 1, 2016.

Interest Rate Swaps — Project Financings

Many of the Company's project subsidiaries entered into interest rate swaps, intended to hedge the risks associated with interest rates on non-recourse project level debt. These swaps amortize in proportion to their respective loans and are floating for fixed where the project subsidiary pays its counterparty the equivalent of a fixed interest payment on a predetermined notional value and will receive quarterly the equivalent of a floating interest payment based on the same notional value. All interest rate swap payments by the project subsidiary and its counterparty are made quarterly and the LIBOR is determined in advance of each interest period.

The following table summarizes the swaps, some of which are forward starting as indicated, related to the Company's project level debt as of December 31, 2017:



	% of Principal		Fixed Interest Rate		Floating Interest Rate	Notional Amount at December 31, 2017 (In millions)		Effective Date	Maturity Date
Alpine	85	%	various		3-Month LIBOR	$	115	various	various
Avra Valley	85	%	2.333	%	3-Month LIBOR	46		November 30, 2012	November 30, 2030
AWAM	100	%	2.47	%	3-Month LIBOR	17		May 22, 2013	May 15, 2031
Blythe	75	%	3.563	%	3-Month LIBOR	13		June 25, 2010	June 25, 2028
Borrego	75	%	1.125	%	3-Month LIBOR	5		April 3, 2013	June 30, 2020
El Segundo	75	%	various		3-Month LIBOR	340		various	various
Kansas South	75	%	2.368	%	6-Month LIBOR	21		June 28, 2013	December 31, 2030
Laredo Ridge	75	%	2.31	%	3-Month LIBOR	75		March 31, 2011	March 31, 2026
Marsh Landing	75	%	3.244	%	3-Month LIBOR	295		June 28, 2013	June 30, 2023
Roadrunner	75	%	4.313	%	3-Month LIBOR	26		September 30, 2011	December 31, 2029
South Trent	75	%	3.265	%	3-Month LIBOR	40		June 15, 2010	June 14, 2020
South Trent	75	%	4.95	%	3-Month LIBOR	21		June 30, 2020	June 14, 2028
Tapestry	75	%	2.21	%	3-Month LIBOR	146		December 30, 2011	December 21, 2021
Tapestry	50	%	3.57	%	3-Month LIBOR	60		December 21, 2021	December 21, 2029
Utah Solar Portfolio	80	%	various		1-Month LIBOR	223		various	September 30, 2036
Viento Funding II	90	%	various		6-Month LIBOR	148		various	various
Viento Funding II	90	%	4.985	%	6-Month LIBOR	65		July 11, 2023	June 30, 2028
Walnut Creek Energy	75	%	various		3-Month LIBOR	239		June 28, 2013	May 31, 2023
WCEP Holdings	90	%	4.003	%	3-Month LIBOR	45		June 28, 2013	May 31, 2023
Total						$	1,940

Annual Maturities

Annual payments based on the maturities of the Company's debt, for the years ending after December 31, 2017, are as follows:



	(In millions)
2018	$	306
2019	714
2020	650
2021	455
2022	653
Thereafter	3,121
Total	$	5,899

Note 11 — Members' Equity

The following table lists the distributions paid on the Company's Class A, Class B, Class C and Class D units during the year ended December 31, 2017:



	Fourth Quarter 2017		Third Quarter 2017		Second Quarter 2017		First Quarter 2017
Distributions per Class A and Class B units	$	0.288	$	0.28	$	0.27	$	0.26
Distributions per Class C and Class D units	$	0.288	$	0.28	$	0.27	$	0.26

On February 15, 2018, the Company declared a quarterly distribution on its Class A, Class B, Class C and Class D units of $0.298 per share payable on March 15, 2018.

During 2017, 2016, and 2015, the Company acquired the Drop Down Assets from NRG, as described in Note 3, Business Acquisitions. The difference between the cash paid and historical value of the acquired Drop Down Assets was recorded as a distribution to/contribution from NRG with the offset to contributed capital. Prior to the date of acquisition, certain of the projects made distributions to NRG and NRG made contributions into certain projects. These amounts are reflected within the Company’s statement of stockholders’ equity as changes in the contributed capital balance.

Note 12 — Segment Reporting

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

The Company generated more than 10% of its revenues from the following customers for the years ended December 31, 2017, 2016 and 2015:



	2017		2016		2015
Customer	Conventional (%)	Renewables (%)	Conventional (%)	Renewables (%)	Conventional (%)	Renewables (%)
SCE	21%	20%	21%	21%	22%	17%
PG&E	12%	11%	12%	11%	12%	12%



	Year ended December 31, 2017
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	336		$	501		$	172		$	—		$	1,009
Cost of operations	77			133			116			—			326
Depreciation and amortization	103			210			21			—			334
Impairment losses	—			44			—			—			44
General and administrative	—			—			—			19			19
Acquisition-related transaction and integration costs	—			—			—			3			3
Operating income (loss)	156			114			35			(22		)	283
Equity in earnings of unconsolidated affiliates	12			59			—			—			71
Other income, net	1			2			—			1			4
Loss on debt extinguishment	—			(3		)	—			—			(3		)
Interest expense	(49		)	(163		)	(10		)	(71		)	(293		)
Net Income (Loss)	$	120		$	9		$	25		$	(92	)	$	62
Balance Sheet
Equity investment in affiliates	$	102		$	1,076		$	—		$	—		$	1,178
Capital expenditures ^(a)	15			4			16			—			35
Total Assets	$	1,897		$	5,811		$	422		$	24		$	8,154

^(a)Includes accruals.



	Year ended December 31, 2016
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	333		$	532		$	170		$	—		$	1,035
Cost of operations	66			128			114			—			308
Depreciation and amortization	80			203			20			—			303
Impairment losses	—			185			—			—			185
General and administrative	—			—			—			14			14
Acquisition-related transaction and integration costs	—			—			—			1			1
Operating income (loss)	187			16			36			(15		)	224
Equity in earnings of unconsolidated affiliates	13			47			—			—			60
Other income, net	1			2			—			—			3
Interest expense	(48		)	(151		)	(7		)	(66		)	(272		)
Net Income (Loss)	$	153		$	(86	)	$	29		$	(81	)	$	15
Balance Sheet
Equity investments in affiliates	$	106		$	1,046		$	—		$	—		$	1,152
Capital expenditures ^(a)	7			2			14			—			23
Total Assets	$	1,993		$	6,114		$	426		$	213		$	8,746

^(a) Includes accruals.



	Year ended December 31, 2015
(In millions)	Conventional Generation			Renewables			Thermal			Corporate			Total
Operating revenues	$	336		$	458		$	174		$	—		$	968
Cost of operations	59			138			126			—			323
Depreciation and amortization	81			203			19			—			303
Impairment losses	—			1			—			—			1
General and administrative	—			—			—			10			10
Acquisition-related transaction and integration costs	—			—			—			3			3
Operating income (loss)	196			116			29			(13		)	328
Equity in earnings of unconsolidated affiliates	14			17			—			—			31
Other income, net	1			2			—			—			3
Loss on debt extinguishment	(7		)	(2		)	—			—			(9		)
Interest expense	(48		)	(151		)	(7		)	(52		)	(258		)
Net Income (Loss)	$	156		$	(18	)	$	22		$	(65	)	$	95

Note 13 — Related Party Transactions

In addition to the transactions and relationships described elsewhere in the notes to the consolidated financial statements, certain subsidiaries of NRG provide services to the Company's project entities. Amounts due to NRG subsidiaries are recorded as accounts payable — affiliate and amounts due to the Company from NRG subsidiaries are recorded as accounts receivable — affiliate in the Company's balance sheet. The disclosures below summarize the Company's material related party transactions with NRG and its subsidiaries that are included in the Company's operating revenues and operating costs.

Power Hedge Contracts by and between Renewable Entities and NRG Texas Power LLC

Certain NRG Wind TE Holdco entities, which are subsidiaries in the Renewables segment, entered into power hedge contracts with NRG Texas Power LLC, a subsidiary of NRG, and generated $16 million of revenue during the year ended December 31, 2015. Effective October 2015, Elbow Creek entered into a PPA with NRG Power Marketing LLC, or NRG Power Marketing, a wholly-owned subsidiary of NRG, as further described below, and the hedge agreement between Elbow Creek and NRG Texas Power LLC was terminated.

Power Purchase Agreements (PPAs) between the Company and NRG Power Marketing

Elbow Creek and Dover are parties to PPAs with NRG Power Marketing and generate revenue under the PPAs, which are recorded to operating revenues in the Company's consolidated statements of operations. For the years ended December 31, 2017 and 2016, Elbow Creek generated revenues of $8 million each year, and Dover generated revenues of $4 million and $5 million, respectively.

Energy Marketing Services Agreement by and between Thermal entities and NRG Power Marketing

NRG Energy Center Dover LLC, NRG Energy Center Minneapolis, NRG Energy Center Phoenix LLC, and NRG Energy Center Paxton LLC, or Thermal entities, are parties to Energy Marketing Services Agreements with NRG Power Marketing, a wholly-owned subsidiary of NRG. Under the agreements, NRG Power Marketing procures fuel and fuel transportation for the operation of Thermal entities. The Thermal entities purchased a total of $9 million of natural gas during each of the years ended December 31, 2017 and 2016. During the year ended December 31, 2015 total purchases of natural gas under the agreement were $13 million.

Operation and Maintenance (O&M) Services Agreements by and between Company's subsidiaries and NRG

Certain of the Company's subsidiaries are party to O&M Services Agreements with NRG, pursuant to which NRG subsidiaries provide necessary and appropriate services to operate and maintain the subsidiaries' plant operations, businesses and thermal facilities. NRG is reimbursed for the provided services, as well as for all reasonable and related expenses and expenditures, and payments to third parties for services and materials rendered to or on behalf of the parties to the agreements. NRG is not entitled to any management fee or mark-up under the agreements. The fees incurred under this agreement were $39 million for the year ended December 31, 2017, and $36 million for each year ended December 31, 2016 and 2015.

The Company had $13 million due to NRG for the services performed during the year ended December 31, 2017 under the O&M Agreements, $5 million of which was paid off as of March 1, 2018. The Company had $22 million due to NRG for the services performed during the year ended December 31, 2016 under the O&M Agreements.

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 $5 million each year for the years ended December 31, 2017 and 2016, and $4 million for the year ended December 31, 2015.

100

Administrative Services Agreement by and between Marsh Landing and NRG West Coast LLC

On December 19, 2016, Marsh Landing entered into an administrative services agreement with NRG West Coast LLC, a wholly owned subsidiary of NRG. The administrative services agreement was previously between Marsh Landing and GenOn Energy Services, LLC, a wholly-owned subsidiary of NRG and was subsequently assigned to and assumed by NRG West Coast LLC. The Company reimbursed costs under this agreement of approximately $15 million, $14 million and $13 million for the years ended December 31, 2017, 2016 and 2015, respectively. There was a balance of $1 million due to NRG West Coast LLC in accounts payable — affiliate as of December 31, 2017 and 2016.

Administrative Services Agreements by and between the Company and NRG Renew Operation & Maintenance LLC

Various wholly-owned subsidiaries of the Company in the Renewables segment are party to administrative services agreements with NRG Renew Operation & Maintenance LLC, or RENOM, a wholly-owned subsidiary of NRG, which provides O&M services to these subsidiaries. The Company incurred total expenses for these services in the amount of $23 million, $13 million and $7 million for the years ended December 31, 2017, 2016 and 2015, respectively. There was a balance of $5 million due to RENOM as of December 31, 2017 and 2016.

Management Services Agreement by and between the Company and NRG

NRG provides the Company with various operational, management, and administrative services, which include human resources, accounting, tax, legal, information systems, treasury, and risk management, as set forth in the Management Services Agreement. As of December 31, 2017, the base management fee was approximately $8.5 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 year ended December 31, 2017, the fee was increased by approximately $1 million per year, primarily due to the acquisition of the March 2017, August 2017 and November 2017 Drop Down Assets, as further described in Note 3, Business Acquisitions. In addition to the base management fee, the Company is also responsible for any expenses that are directly incurred and paid for by NRG on behalf of the Company. Costs incurred under this agreement were approximately $10 million for each of the years ended December 31, 2017 and 2016, and $8 million for the year ended December 31, 2015. There was a balance of $4 million in accounts payable — affiliate due to NRG as of December 31, 2017, which the Company paid off in January 2018.

EPC Agreement by and between NECP and NRG

On October 31, 2016, NRG Business Services LLC, a subsidiary of NRG, and NECP, a wholly owned subsidiary of the Company, entered into an EPC agreement for the construction of a 73 MWt district energy system for NECP to provide 150 kpph of steam, 6,750 tons of chilled water and 7.5 MW of emergency backup power service to UPMC Mercy. The initial term of the energy services agreement with UPMC Mercy will be for a period of twenty years from the service commencement date. Pursuant to the terms of the EPC agreement, NECP agreed to pay NRG Business Services LLC $79 million, subject to adjustment based upon certain conditions in the EPC agreement, upon substantial completion of the project. The project is expected to reach COD in the first half of 2018. As of December 31, 2017, the parties made a number of amendments to the EPC Agreement, based on customer change orders, to increase the capacity of the district energy system from 73 MWt to 80 MWt, which also increased the payment from $79 million to $88 million.

Note 14 — Commitments and Contingencies

Operating Lease Commitments

The Company leases certain facilities and equipment under operating leases, some of which include escalation clauses, expiring on various dates through 2048. The effects of these scheduled rent increases, leasehold incentives, and rent concessions are recognized on a straight-line basis over the lease term unless another systematic and rational allocation basis is more representative of the time pattern in which the leased property is physically employed. Lease expense under operating leases was $17 million, $15 million and $10 million for the years ended December 31, 2017, 2016 and 2015, respectively.

The Company's future minimum lease commitments under operating leases are $9 million for each of the years ending December 31, 2018 through 2022, and $151 million thereafter.

Period

101

Gas and Transportation Commitments

The Company has entered into contractual arrangements to procure power, fuel and associated transportation services. For the years ended December 31, 2017, 2016 and 2015, the Company purchased $34 million, $32 million and $40 million, respectively, under such arrangements. As further described in Note 13 Related Party Transactions, these purchases include intercompany transactions between certain Thermal entities and NRG Power Marketing under the Energy Marketing Services Agreements in the amount of $9 million for each of the years ended December 31, 2017 and 2016. Total intercompany purchases of natural gas under the agreement were $13 million for the year ended December 31, 2015.

As of December 31, 2017, the Company's commitments under such outstanding agreements are estimated as follows:



Period	(In millions)
2018	$	11
2019	5
2020	3
2021	3
2022	3
Thereafter	16
Total	$	41

Contingencies

The Company's material legal proceedings are described below. The Company believes that it has valid defenses to these legal proceedings and intends to defend them vigorously. The Company records reserves for estimated losses from contingencies when information available indicates that a loss is probable and the amount of the loss, or range of loss, can be reasonably estimated. As applicable, the Company has established an adequate reserve for the matters discussed below. In addition, legal costs are expensed as incurred. Management assesses such matters based on current information and makes a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought and the probability of success. The Company is unable to predict the outcome of the legal proceedings below or reasonably estimate the scope or amount of any associated costs and potential liabilities. As additional information becomes available, management adjusts its assessment and estimates of such contingencies accordingly. Because litigation is subject to inherent uncertainties and unfavorable rulings or developments, it is possible that the ultimate resolution of the Company's liabilities and contingencies could be at amounts that are different from its currently recorded reserves and that such difference could be material.

In addition to the legal proceedings noted below, the Company and its subsidiaries are party to other litigation or legal proceedings arising in the ordinary course of business. In management's opinion, the disposition of these ordinary course matters will not materially adversely affect the Company's consolidated financial position, results of operations, or cash flows.

Braun v. NRG Yield, Inc. — On April 19, 2016, plaintiffs filed a putative class action lawsuit against NRG Yield, Inc., the current and former members of its board of directors individually, and other parties in California Superior Court in Kern County, CA. Plaintiffs allege various violations of the Securities Act due to the defendants’ alleged failure to disclose material facts related to low wind production prior to NRG Yield, Inc.'s June 22, 2015 Class C common stock offering. Plaintiffs seek compensatory damages, rescission, attorney’s fees and costs. The defendants filed objections and a motion challenging jurisdiction on October 18, 2016. On December 1, 2017, the parties agreed to a stipulation which provides the plaintiffs' opposition is due on March 6, 2018 and the defendants' reply is due on May 4, 2018.

Ahmed v. NRG Energy, Inc. and the NRG Yield Board of Directors — On September 15, 2016, plaintiffs filed a putative class action lawsuit against NRG Energy, Inc., the directors of NRG Yield, Inc., and other parties in the Delaware Chancery Court. The complaint alleges that the defendants breached their respective fiduciary duties with regard to the recapitalization of NRG Yield, Inc. common stock in 2015. The plaintiffs generally seek economic damages, attorney’s fees and injunctive relief. The defendants filed a motion to dismiss the lawsuit on December 21, 2016. Plaintiffs filed their objection to the motion to dismiss on February 15, 2017. The defendants' reply was filed on March 24, 2017. The court heard oral argument on the defendants' motion to dismiss on June 20, 2017. On September 7, 2017, the court requested additional briefing which the parties provided on September 21, 2017. On December 11, 2017, the court dismissed the lawsuit with prejudice, thereby ending the case.

GenOn Noteholders' Lawsuit — On December 13, 2016, certain indenture trustees for an ad hoc group of holders, or the Noteholders, of the GenOn Energy, Inc., or GenOn, 7.875% Senior Notes due 2017, 9.500% Notes due 2018, and 9.875% Notes due 2020, and the GenOn Americas Generation, LLC 8.50% Senior Notes due 2021 and 9.125% Senior Notes due 2031, along with certain of the Noteholders, filed a complaint in the Superior Court of the State of Delaware against NRG and GenOn alleging

102

certain claims related to the Services Agreement between NRG and GenOn. On April 30, 2017, the Noteholders filed an amended complaint that asserts additional claims of fraudulent transfer, insider preference and breach of fiduciary duties. In addition to NRG and GenOn, the amended complaint names NRG Yield LLC and certain current and former officers and directors of GenOn as defendants. The plaintiffs, among other things, generally seek return of all monies paid under the Services Agreement and any other damages that the court deems appropriate. On April 28, 2017, the bondholders filed an amended complaint adding the GenOn directors and officers as defendants and asserting claims that they breached certain fiduciary duties. Plaintiffs specifically allege that the transfer of Marsh Landing to NRG Yield LLC constituted a fraudulent transfer. On June 12, 2017, certain GenOn entities, NRG and certain holders of the GenOn and GenOn Americas Generation, LLC senior notes entered into a restructuring support and lock-up agreement. On December 14, 2017, a settlement agreement was entered into between GenOn and NRG which should ultimately resolve this lawsuit.

103

Note 15 — Unaudited Quarterly Data

Refer to Note 2, Summary of Significant Accounting Policies and Note 3, Business Acquisitions for a description of the effect of unusual or infrequently occurring events during the quarterly periods. Below is summarized unaudited quarterly financial data, which includes the results of the November 2017 Drop Down Assets Acquisition and its impact on every quarter of the 2017 and 2016 results, which were recast to include the November 2017 Drop Down Assets, where applicable:



	Quarter Ended
	December 31,			September 30,			June 30,		March 31,
	2017
	(In millions)
Operating Revenues	$	231		$	269		$	288	$	221

Operating Revenues (as previously reported)	N/A			265			284		218
Change	N/A			4			4		3

Operating Income	19			85			124		55

Operating Income (as previously reported)	N/A			95			122		54
Change	N/A			(10		)	2		1

Net (Loss) Income	(38		)	41			59		—

Net Income (as previously reported)	N/A			52			57		1
Change	N/A			$	(11	)	$	2	$	(1	)



	Quarter Ended
	December 31,			September 30,		June 30,		March 31,
	2016
	(In millions)
Operating Revenues	$	235		$	276	$	287	$	237

Operating Revenues (as previously reported)	232			272		283		234
Change	3			4		4		3

Operating (Loss) Income	(100		)	120		130		74

Operating (Loss) Income (as previously reported)	(99		)	118		128		73
Change	(1		)	2		2		1

Net (Loss) Income	(138		)	68		80		5

Net (Loss) Income (as previously reported)	(137		)	67		79		6
Change	$	(1	)	$	1	$	1	$	(1	)

104

Note 16 — Condensed Consolidating Financial Information

As of December 31, 2017, Yield Operating LLC had outstanding $500 million of the 2024 Senior Notes and $350 million of the 2026 Senior Notes, collectively Senior Notes, as described in Note 10, Long-term Debt. These Senior Notes are guaranteed by the Company, as well as certain of the Company's subsidiaries, or guarantor subsidiaries. These guarantees are both joint and several. The non-guarantor subsidiaries include the rest of the Company's subsidiaries, including the ones that are subject to project financing.

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

NRG Yield LLC

Alta Wind 1-5 Holding Company, LLC

Alta Wind Company, LLC

NRG Energy Center Omaha Holdings LLC

NRG Energy Center Omaha LLC

NYLD Fuel Cell Holdings LLC

UB Fuel Cell, LLC

NRG South Trent Holdings LLC

NRG Yield DGPV Holding LLC

NRG Yield RPV Holding LLC

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

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

In this presentation, Yield LLC consists of parent company operations. Guarantor subsidiaries and non-guarantor subsidiaries of Yield LLC are reported on an equity basis. For companies acquired, the fair values of the assets and liabilities acquired have been presented on a push-down accounting basis. As described in Note 3, Business Acquisitions, the Company completed the acquisition of the November 2017 Drop Down Assets, August 2017 Drop Down Assets, and March 2017 Drop Down Assets from NRG on November 1, 2017, August 1, 2017 and March 27, 2017, respectively. The guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. Accordingly, the Company prepared its condensed consolidating financial statements to reflect the transfers as if they had taken place from the beginning of the financial statements period.

In addition, the condensed parent company financial statements are provided in accordance with Rule 12-04, Schedule I of Regulation S-X, as the restricted net assets of Yield LLC’s subsidiaries exceed 25 percent of the consolidated net assets of Yield LLC. These statements should be read in conjunction with the consolidated statements and notes thereto of NRG Yield LLC. For a discussion of Yield LLC's long-term debt, see Note 10, Long-term Debt. For a discussion of Yield LLC's commitments and contingencies, see Note 14, Commitments and Contingencies. For a discussion of Yield LLC's distributions to Yield, Inc. and NRG Energy, see Note 11, Members' Equity.

105

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

For the year ended December 31, 2017



	NRG Yield LLC ^(a)		Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations^(b)			Consolidated
	(In millions)
Operating Revenues
Total operating revenues	$	—	$	21		$	988		$	1		$	(1	)	$	1,009
Operating Costs and Expenses									—
Cost of operations	—		14			312			1			(1		)	326
Depreciation and amortization	—		5			329			—			—			334
Impairment losses	—		—			44			—			—			44
General and administrative	—		—			—			19			—			19
Acquisition-related transaction and integration costs	—		—			—			3			—			3
Total operating costs and expenses	—		19			685			23			(1		)	726
Operating (Loss) Income	—		2			303			(22		)	—			283
Other Income (Expense)
Equity in earnings (losses) of consolidated affiliates	136		(16		)	—			126			(246		)	—
Equity in earnings of unconsolidated affiliates	—		22			21			28			—			71
Other income, net	1		—			3			—			—			4
Loss on debt extinguishment	—		—			(3		)	—			—			(3		)
Interest expense	—		—			(222		)	(71		)	—			(293		)
Total other income (expense), net	137		6			(201		)	83			(246		)	(221		)
Net Income	137		8			102			61			(246		)	62
Less: Net loss attributable to noncontrolling interests	—		—			(5		)	(75		)	5			(75		)
Net Income Attributable to NRG Yield LLC	$	137	$	8		$	107		$	136		$	(251	)	$	137

^(a) Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

106

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME

For the year ended December 31, 2017



	NRG Yield LLC^(a)		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations^(b)			Consolidated
	(In millions)
Net Income	$	137	$	8	$	102		$	61		$	(246	)	$	62
Other Comprehensive Income
Unrealized gain on derivatives	17		1		16			17			(34		)	17
Other comprehensive income	17		1		16			17			(34		)	17
Comprehensive Income	154		9		118			78			(280		)	79
Less: Comprehensive loss attributable to noncontrolling interests	—		—		(5		)	(75		)	5			(75		)
Comprehensive Income Attributable to NRG Yield LLC	$	154	$	9	$	123		$	153		$	(285	)	$	154

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

107

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

December 31, 2017



	NRG Yield LLC^(a)		Other Guarantor Subsidiaries		Non-Guarantor Subsidiaries		NRG Yield Operating LLC (Note Issuer)		Eliminations^(b)			Consolidated
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	22	$	—	$	124	$	—	$	—		$	146
Restricted cash	—		—		168		—		—			168
Accounts receivable — trade	1		2		92		1		—			96
Inventory	—		1		38		—		—			39
Notes receivable — current	—		—		13		—		—			13
Prepayments and other current assets	—		—		18		1		—			19
Total current assets	23		3		453		2		—			481

Property, plant and equipment, net	—		58		5,146		—		—			5,204
Other Assets
Investment in consolidated subsidiaries	1,823		460		—		3,177		(5,460		)	—
Equity investments in affiliates	—		233		577		368		—			1,178
Intangible assets, net	—		55		1,173		—		—			1,228
Other non-current assets	—		—		63		—		—			63
Total other assets	1,823		748		1,813		3,545		(5,460		)	2,469
Total Assets	$	1,846	$	809	$	7,412	$	3,547	$	(5,460	)	$	8,154

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

108

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

(Continued)

December 31, 2017



	NRG Yield LLC ^(a)			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Eliminations^(b)			Consolidated
LIABILITIES AND MEMBERS' EQUITY	(In millions)
Current Liabilities
Current portion of long-term debt — external	$	—		$	—		$	306		$	—		$	—		$	306
Accounts payable — trade	—			2			25			—			—			27
Accounts payable — affiliate	—			5			27			16			—			48
Derivative instruments	—			—			17			—			—			17
Accrued expenses and other current liabilities	—			1			61			25			—			87
Total current liabilities	—			8			436			41			—			485
Other Liabilities
Long-term debt — external	—			—			4,025			896			—			4,921
Long-term debt — affiliate	—			—			—			618			—			618
Derivative instruments	—			—			31			—			—			31
Other non-current liabilities	—			—			84			7			—			91
Total non-current liabilities	—			—			4,140			1,521			—			5,661
Total Liabilities	—			8			4,576			1,562			—			6,146
Commitments and Contingencies
Members' Equity
Contributed capital	1,897			863			2,871			2,097			(5,831		)	1,897
Retained earnings (accumulated deficit)	17			(61		)	(21		)	(206		)	288			17
Accumulated other comprehensive loss	(68		)	(1		)	(71		)	(68		)	140			(68		)
Noncontrolling interest	—			—			57			162			(57		)	162
Total Members' Equity	1,846			801			2,836			1,985			(5,460		)	2,008
Total Liabilities and Members’ Equity	$	1,846		$	809		$	7,412		$	3,547		$	(5,460	)	$	8,154

^(a) Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

109

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS

For the year ended December 31, 2017



	NRG Yield LLC^(a)			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries			NRG Yield Operating LLC (Note Issuer)			Consolidated
	(In millions)
Net Cash Provided by (Used in) Operating Activities	$	—		$	58		$	529		$	(71	)	$	516
Cash Flows from Investing Activities
Changes in investments in consolidated subsidiaries	(15		)	—			—			15			—
Acquisition of Drop Down Assets, net of cash acquired	—			—			—			(250		)	(250		)
Capital expenditures	—			(4		)	(27		)	—			(31		)
Cash receipts from notes receivable	—			—			17			—			17
Return of investment from unconsolidated affiliates	—			10			14			23			47
Investments in unconsolidated affiliates	—			(64		)	(7		)	(2		)	(73		)
Other	—			—			7			—			7
Net Cash Provided by (Used in) Investing Activities	(15		)	(58		)	4			(214		)	(283		)
Cash Flows from Financing Activities
Net contributions from noncontrolling interests	—			—			2			11			13
Net distributions and return of capital to NRG prior to the acquisition of Drop Down Assets	—			—			(13		)	(7		)	(20		)
Transfer of funds under intercompany cash management arrangement	(5		)	—			(1		)	6			—
Proceeds from the issuance of Class C units	33			—			—			—			33
(Payments of) proceeds from distributions	(202		)	—			(220		)	220			(202		)
Proceeds from the revolving credit facility	—			—			—			55			55
Proceeds from issuance of long-term debt	—			—			41			—			41
Payments of debt issuance costs	—			—			(4		)	—			(4		)
Payments for long-term debt — external	—			—			(332		)	—			(332		)
Net Cash (Used in) Provided by Financing Activities	(174		)	—			(527		)	285			(416		)
Net (Decrease) Increase in Cash, Cash Equivalents and Restricted Cash	(189		)	—			6			—			(183		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	211			—			286			—			497
Cash, Cash Equivalents and Restricted Cash at End of Period	$	22		$	—		$	292		$	—		$	314

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

110

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

For the Year Ended December 31, 2016



	NRG Yield LLC^{(a) (c)}			Other Guarantor Subsidiaries		Non-Guarantor Subsidiaries ^(c)			NRG Yield Operating LLC (Note Issuer) ^(c)			Eliminations^{(b) (c)}			Consolidated
	(In millions)
Operating Revenues
Total operating revenues	$	—		$	22	$	1,013		$	1		$	(1	)	$	1,035
Operating Costs and Expenses
Cost of operations	—			14		294			1			(1		)	308
Depreciation and amortization	—			5		298			—			—			303
Impairment losses	—			—		185			—			—			185
General and administrative	2			—		—			12			—			14
Acquisition-related transaction and integration costs	—			—		—			1			—			1
Total operating costs and expenses	2			19		777			14			(1		)	811
Operating Income (Loss)	(2		)	3		236			(13		)	—			224
Other Income (Expense)
Equity in earnings (losses) of consolidated affiliates	128			10		—			66			(204		)	—
Equity in earnings of unconsolidated affiliates	—			9		21			30			—			60
Other income, net	—			—		3			—			—			3
Interest expense	—			—		(206		)	(66		)	—			(272		)
Total other income (expense)	128			19		(182		)	30			(204		)	(209		)
Net Income	126			22		54			17			(204		)	15
Less: Net loss attributable to noncontrolling interests	—			—		(1		)	(111		)	1			(111		)
Net Income Attributable to NRG Yield LLC	$	126		$	22	$	55		$	128		$	(205	)	$	126

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

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

111

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME

For the Year Ended December 31, 2016



	NRG Yield LLC ^{(a) (c)}		Other Guarantor Subsidiaries		Non-Guarantor Subsidiaries ^(c)			NRG Yield Operating LLC (Note Issuer) ^(c)			Eliminations^{(b) (c)}			Consolidated
	(In millions)
Net Income	$	126	$	22	$	54		$	17		$	(204	)	$	15
Other Comprehensive Income
Unrealized gain on derivatives	13		1		10			13			(24		)	13
Other comprehensive income	13		1		10			13			(24		)	13
Comprehensive Income	139		23		64			30			(228		)	28
Less: Comprehensive loss attributable to noncontrolling interests	—		—		(1		)	(111		)	1			(111		)
Comprehensive Income Attributable to NRG Yield LLC	$	139	$	23	$	65		$	141		$	(229	)	$	139

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

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

112

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

December 31, 2016



	NRG Yield LLC^(a)(c)		Other Guarantor Subsidiaries		Non-Guarantor Subsidiaries^(c)		NRG Yield Operating LLC (Note Issuer) ^(c)		Eliminations^(b)(c)			Consolidated
ASSETS	(In millions)
Current Assets
Cash and cash equivalents	$	211	$	—	$	110	$	—	$	—		$	321
Restricted cash	—		—		176		—		—			176
Accounts receivable — trade	—		2		94		—		—			96
Inventory	—		2		37		—		—			39
Notes receivable — current	—		—		16		—		—			16
Prepayments and other current assets	—		—		21		1		—			22
Total current assets	211		4		454		1		—			670

Property, plant and equipment, net	—		59		5,495		—		—			5,554
Other Assets
Investment in consolidated subsidiaries	1,927		527		—		3,272		(5,726		)	—
Equity investments in affiliates	—		171		600		381		—			1,152
Intangible assets, net	—		56		1,247		—		—			1,303
Other non-current assets	—		—		66		1		—			67
Total other assets	1,927		754		1,913		3,654		(5,726		)	2,522
Total Assets	$	2,138	$	817	$	7,862	$	3,655	$	(5,726	)	$	8,746

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

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

113

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEETS

(Continued)

December 31, 2016



	NRG Yield LLC ^{(a) (c)}			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries ^(c)			NRG Yield Operating LLC (Note Issuer)^(c)			Eliminations ^{(b) (c)}			Consolidated
LIABILITIES AND MEMBERS' EQUITY	(In millions)
Current Liabilities
Current portion of long-term debt — external	$	—		$	—		$	323		$	—		$	—		$	323
Accounts payable — trade	—			2			18			3			—			23
Accounts payable — affiliate	—			7			15			18			—			40
Derivative instruments	—			—			33			—			—			33
Accrued expenses and other current liabilities	—			1			60			24			—			85
Total current liabilities	—			10			449			45			—			504
Other Liabilities
Long-term debt — external	—			—			4,289			839			—			5,128
Long-term debt — affiliate	—			—			—			618			—			618
Accounts payable — affiliate	—			—			9			—			—			9
Derivative instruments	—			—			46			—			—			46
Other non-current liabilities	—			—			77			—			—			77
Total non-current liabilities	—			—			4,421			1,457			—			5,878
Total Liabilities	—			10			4,870			1,502			—			6,382
Commitments and Contingencies
Members' Equity
Contributed capital	2,179			874			2,972			2,155			(6,001		)	2,179
Retained earnings (accumulated deficit)	44			(65		)	43			(143		)	165			44
Accumulated other comprehensive loss	(85		)	(2		)	(87		)	(85		)	174			(85		)
Noncontrolling interest	—			—			64			226			(64		)	226
Total Members' Equity	2,138			807			2,992			2,153			(5,726		)	2,364
Total Liabilities and Members’ Equity	$	2,138		$	817		$	7,862		$	3,655		$	(5,726	)	$	8,746

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

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

114

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS

For the Year Ended December 31, 2016



	NRG Yield LLC ^{(a) (b)}			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries ^(b)			NRG Yield Operating LLC (Note Issuer)^(b)			Consolidated

Net Cash Provided by (Used in) Operating Activities	$	—		$	62		$	554		$	(39	)	$	577
Cash Flows from Investing Activities
Changes in investments in consolidated subsidiaries	325			—			(21		)	(304		)	—
Acquisition of Drop Down Assets	—			—			—			(77		)	(77		)
Capital expenditures	—			—			(20		)	—			(20		)
Cash receipts from notes receivable	—			—			17			—			17
Return of investment from unconsolidated affiliates	—			16			—			12			28
Investments in unconsolidated affiliates	—			(80		)	(3		)	—			(83		)
Other	—			—			4			—			4
Net Cash Used in Investing Activities	325			(64		)	(23		)	(369		)	(131		)
Cash Flows from Financing Activities
Transfer of funds under intercompany cash management arrangement	44			2			—			(46		)	—
Net contributions from noncontrolling interests	—			—			—			5			5
Net distributions and return of capital to NRG prior to the acquisition of Drop Down Assets	—			—			(174		)	(10		)	(184		)
(Payments of) proceeds from distributions	(173		)	—			(420		)	420			(173		)
Proceeds from the revolving credit facility	—			—			—			60			60
Payments for the revolving credit facility	—			—			—			(366		)	(366		)
Proceeds from the issuance of long-term debt - external	—			—			390			350			740
Payments of debt issuance costs	—			—			(10		)	(5		)	(15		)
Payments for long-term debt — external	—			—			(269		)	—			(269		)
Net Cash Provided by (Used in) Financing Activities	(129		)	2			(483		)	408			(202		)
Net (Decrease) Increase in Cash, Cash Equivalents and Restricted Cash	196			—			48			—			244
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	15			—			238			—			253
Cash, Cash Equivalents and Restricted Cash at End of Period	$	211		$	—		$	286		$	—		$	497

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

115

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

For the Year Ended December 31, 2015



	NRG Yield LLC^{(a) (c)}		Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries ^(c)			NRG Yield Operating LLC (Note Issuer)^(c)			Eliminations^{(b) (c)}			Consolidated
	(In millions)
Operating Revenues
Total operating revenues	$	—	$	21		$	937		$	10		$	—		$	968
Operating Costs and Expenses
Cost of operations	—		14			309			—			—			323
Depreciation and amortization	—		4			299			—			—			303
Impairment losses	—		—			1			—			—			1
General and administrative	—		—			—			10			—			10
Acquisition-related transaction and integration costs	—		—			—			3			—			3
Total operating costs and expenses	—		18			609			13			—			640
Operating Income (Loss)	—		3			328			(3		)	—			328
Other Income (Expense)
Equity in earnings (losses) of consolidated affiliates	157		(43		)	—			125			(239		)	—
Equity in (losses) earnings of unconsolidated affiliates	—		(2		)	8			25			—			31
Other income, net	—		—			3			—			—			3
Loss on debt extinguishment	—		—			(9		)	—			—			(9		)
Interest expense	—		—			(206		)	(52		)	—			(258		)
Total other income (expense), net	157		(45		)	(204		)	98			(239		)	(233		)
Net Income (Loss)	157		(42		)	124			95			(239		)	95
Less: Net loss attributable to noncontrolling interests	—		—			(2		)	(62		)	2			(62		)
Net Income (Loss) Attributable to NRG Yield LLC	$	157	$	(42	)	$	126		$	157		$	(241	)	$	157

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

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

116

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME

For the Year Ended December 31, 2015



	NRG Yield LLC ^{(a) (c)}			Other Guarantor Subsidiaries			Non-Guarantor Subsidiaries^(c)			NRG Yield Operating LLC (Note Issuer) ^(c)			Eliminations ^{(b) (c)}			Consolidated
	(In millions)
Net Income (Loss)	$	157		$	(42	)	$	124		$	95		$	(239	)	$	95
Other Comprehensive Loss
Unrealized loss on derivatives	(16		)	—			(16		)	(17		)	32			(17		)
Other comprehensive loss	(16		)	—			(16		)	(17		)	32			(17		)
Comprehensive Income (Loss)	141			(42		)	108			78			(207		)	78
Less: Comprehensive loss attributable to noncontrolling interests	—			—			(2		)	(63		)	2			(63		)
Comprehensive Income (Loss) Attributable to NRG Yield LLC	$	141		$	(42	)	$	110		$	141		$	(209	)	$	141

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

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

117

NRG YIELD LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS

For the Year Ended December 31, 2015




	NRG Yield LLC ^{(a) (b)}			Other Guarantor Subsidiaries				Non-Guarantor Subsidiaries^(b)			NRG Yield Operating LLC (Note Issuer) ^(b)			Consolidated
	(In millions)
Net Cash Provided by (Used in) Operating Activities	$	—		$	19			$	423		$	(18	)	$	424
Cash Flows from Investing Activities
Changes in investments in consolidated subsidiaries	(464		)	—				285			179			—
Acquisition of businesses, net of cash acquired	—			—				—			(37		)	(37		)
Acquisition of Drop Down Assets, net of cash acquired	—			—				—			(698		)	(698		)
Capital expenditures	—			—				(29		)	—			(29		)
Cash receipts from notes receivable	—			—				17			—			17
Return of investment from unconsolidated affiliates	—			—				—			42			42
Investments in unconsolidated affiliates	—			(28		)	—	—			(374		)	(402		)
Other	—			—				9			—			9
Net Cash (Used in) Provided by Investing Activities	(464		)	(28		)		282			(888		)	(1,098		)
Cash Flows from Financing Activities
Transfer of funds under intercompany cash management arrangement	(309		)	9				—			300			—
Net contributions from noncontrolling interests	—			—				—			122			122
Net distributions and return of capital to NRG prior to the acquisition of Drop Down Assets	—			—				(79		)	—			(79		)
Proceeds from the issuance of Class C units	599			—				—			—			599
(Payments of) proceeds from distributions	(139		)	—				(392		)	392			(139		)
Proceeds from the revolving credit facility	—			—				—			551			551
Payments for the revolving credit facility	—			—				—			(245		)	(245		)
Proceeds from issuance of long-term debt — external	—			—				6			—			6
Proceeds from issuance of long-term debt — affiliate	—			—				—			281			281
Payments for long-term debt — external	—			—				(241		)	(494		)	(735		)
Payment of debt issuance costs	—			—				(6		)	(1		)	(7		)
Net Cash Provided by (Used in) Financing Activities	151			9				(712		)	906			354
Net (Decrease) Increase in Cash, Cash Equivalents and Restricted Cash	(313		)	—				(7		)	—			(320		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	328			—				245			—			573
Cash, Cash Equivalents and Restricted Cash at End of Period	$	15		$	—			$	238		$	—		$	253

^(a)Shown separately from the other guarantors in lieu of preparing Schedule I pursuant to the requirements of Rule 5-04(c) of Regulation S-X.

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

118

EXHIBIT INDEX



Number	Description	Method of Filing
2.1	Purchase and Sale Agreement, dated as of May 5, 2014, by and between NRG Gas Development Company, LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.1 to NRG Yield, Inc.’s Current Report on Form 8-K filed on May 9, 2014.
2.2	Purchase and Sale Agreement, dated as of May 5, 2014, by and between NRG Solar PV LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.2 to NRG Yield, Inc.’s Current Report on Form 8-K filed on May 9, 2014.
2.3	Purchase and Sale Agreement, dated as of May 5, 2014, by and between NRG Solar PV LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.3 to NRG Yield, Inc.’s Current Report on Form 8-K filed on May 9, 2014.
2.4	Purchase and Sale Agreement, dated June 3, 2014, by and among NRG Yield, Inc., NRG Yield Operating LLC, Terra-Gen Finance Company, LLC, NTD AWAM Holdings, LLC, CHIPS Alta Wind X Holding Company, LLC and CHIPS Alta Wind XI Holding Company, LLC.	Incorporated herein by reference to Exhibit 10.1 to NRG Yield, Inc.’s Current Report on Form 8-K filed on June 9, 2014.
2.5	Purchase and Sale Agreement, dated as of November 4, 2014, by and between NRG Wind LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.1 to NRG Yield, Inc.’s Current Report on Form 8-K filed on November 7, 2014.
2.6	Purchase and Sale Agreement, dated as of November 4, 2014, by and between NRG Arroyo Nogales LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.2 to NRG Yield, Inc.’s Current Report on Form 8-K filed on November 7, 2014.
2.7*^	Purchase and Sale Agreement, dated as of June 17, 2015, by and between EFS Desert Sun, LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.1 to NRG Yield, Inc.’s Quarterly Report on Form 10-Q filed on August 4, 2015.
2.8	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 NRG Yield, Inc.’s Current Report on Form 8-K filed on September 21, 2015.
2.9	Purchase and Sale Agreement, dated as of August 8, 2016, between NRG Solar CVSR Holdings 2 LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.1 to NRG Yield, Inc.'s Current Report on Form 8-K, filed on August 9, 2016.
2.10*	Purchase and Sale Agreement, dated as of February 6, 2018, by and between NRG Gas Development Company, LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 2.10 to NRG Yield, Inc.'s Annual Report on Form 10-K, filed on March 1, 2018.
3.1	Certificate of Formation of NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 3.01(a) to the Company's Registration Statement on Form S-4 filed on April 13, 2015.
3.2	Certificate of Amendment of Certificate of Formation of NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 3.01(b) to the Company's Registration Statement on Form S-4 filed on April 13, 2015.
3.3	Second Amended and Restated Limited Liability Company Agreement of NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 3.02 to the Company's Registration Statement on Form S-4 filed on April 13, 2015.
3.4	Certificate of Formation of NRG Yield LLC.	Incorporated herein by reference to Exhibit 3.03(a) to the Company's Registration Statement on Form S-4 filed on April 13, 2015.
3.5	Certificate of Amendment of Certificate of Formation of NRG Yield LLC.	Incorporated herein by reference to Exhibit 3.03(b) to the Company's Registration Statement on Form S-4 filed on April 13, 2015.
3.6	Third Amended and Restated Limited Liability Company Agreement of NRG Yield LLC, dated as of May 14, 2015.	Incorporated herein by reference to Exhibit 10.4 to NRG Yield, Inc.'s Current Report on Form 8-K filed on May 15, 2015.
4.1	Indenture, dated August 5, 2014, among NRG Yield Operating LLC, the guarantors named therein and Law Debenture Trust Company of New York.	Incorporated herein by reference to Exhibit 4.1 to NRG Yield, Inc.'s Current Report on Form 8-K filed on August 5, 2014.

119



4.2	Form of 5.375% Senior Note due 2024.	Incorporated herein by reference to Exhibit 4.2 to NRG Yield, Inc.'s Current Report on Form 8-K filed on August 5, 2014.
4.3	Registration Rights Agreement, dated August 5, 2014, among NRG Yield Operating LLC, the guarantors named therein and Merrill Lynch, Pierce, Fenner & Smith Incorporated, as representative of the initial purchasers.	Incorporated herein by reference to Exhibit 4.3 to NRG Yield, Inc.'s Current Report on Form 8-K filed on August 5, 2014.
4.4	Supplemental Indenture, dated as of November 7, 2014, among NRG Yield Operating LLC, the guarantors named therein and Law Debenture Trust Company of New York.	Incorporated herein by reference to Exhibit 4.1 to NRG Yield, Inc.'s Current Report on Form 8-K filed on November 13, 2014.
4.5	Supplemental Indenture, dated as of February 25, 2015, among NRG Yield Operating LLC, the guarantors named therein and Law Debenture Trust Company of New York.	Incorporated herein by reference to Exhibit 4.1 to NRG Yield, Inc.'s Current Report on Form 8-K filed on February 27, 2015.
4.6	Third Supplemental Indenture, dated as of April 10, 2015, among NRG Yield Operating LLC, NRG Yield LLC, the other guarantors named therein and Law Debenture Trust Company of New York.	Incorporated herein by reference to Exhibit 4.07 to the Company's Registration Statement on Form S-4 filed on April 13, 2015.
4.7	Fourth Supplemental Indenture, dated as of May 8, 2015, among NRG Yield Operating LLC, the guarantors named therein and Law Debenture Trust Company of New York.	Incorporated herein by reference to Exhibit 4.1 to NRG Yield, Inc.'s Current Report on Form 8-K filed on May 8, 2015.
4.8	Indenture, dated June 29, 2015, among NRG Yield, Inc., NRG Yield Operating LLC and NRG Yield LLC, as Guarantors, and Wilmington Trust, National Association, as Trustee.	Incorporated herein by reference to Exhibit 4.1 to NRG Yield, Inc.'s Current Report on Form 8-K filed on June 29, 2015.
4.9	Form of 3.25% Convertible Senior Note due 2020.	Incorporated herein by reference to Exhibit 4.2 to NRG Yield, Inc.'s Current Report on Form 8-K filed on June 29, 2015.
4.10	Indenture, dated August 18, 2016, among NRG Yield Operating LLC, the guarantors named therein and Law Debenture Trust Company of New York.	Incorporated herein by reference to Exhibit 4.1 to the Registrant's Current Report on Form 8-K, filed on August 18, 2016.
4.11	Form of 5.000% Senior Note due 2026.	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K, filed on August 18, 2016.
4.12	Registration Rights Agreement, dated August 18, 2016, among NRG Yield Operating LLC, the guarantors named therein and J.P. Morgan Securities LLC, as representative of the initial purchasers.	Incorporated herein by reference to Exhibit 4.3 to the Registrant's Current Report on Form 8-K, filed on August 18, 2016.
4.13	Fifth Supplemental Indenture, dated as of January 29, 2018, among NRG Yield Operating LLC, the guarantors named therein and Delaware Trust Company (as successor in interest to Law Debenture Trust Company of New York).	Incorporated herein by reference to Exhibit 4.1 to the Registrant's Current Report on Form 8-K, filed on January 31, 2018.
4.14	Supplemental Indenture, dated as of January 29, 2018, among NRG Yield Operating LLC, the guarantors named therein and the Delaware Trust Company (as successor in interest to Law Debenture Trust Company of New York).	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K, filed on January 31, 2018.
10.1	Amended and Restated Registration Rights Agreement, dated as of May 14, 2015, by and between NRG Energy, Inc. and NRG Yield, Inc.	Incorporated herein by reference to Exhibit 10.2 to NRG Yield, Inc.'s Current Report on Form 8-K filed on May 15, 2015.
10.2	Amended and Restated Exchange Agreement, dated as of May 14, 2015, by and among NRG Energy, Inc., NRG Yield, Inc. and NRG Yield LLC.	Incorporated herein by reference to Exhibit 10.1 to NRG Yield, Inc.'s Current Report on Form 8-K filed on May 15, 2015.
10.3	Second Amended and Restated Right of First Offer Agreement, dated as of February 24, 2017, by and between NRG Energy, Inc. and NRG Yield, Inc.	Incorporated herein by reference to Exhibit 10.3 to NRG Yield, Inc.'s Annual Report on Form 10-K filed on February 28, 2017.
10.4	Management Services Agreement, dated as of July 22, 2013, by and between NRG Energy, Inc., NRG Yield, Inc., NRG Yield LLC and NRG Yield Operating LLC.	Incorporated herein by reference to Exhibit 10.4 to NRG Yield, Inc.'s Current Report on Form 8-K filed on July 26, 2013.
10.5	Trademark License Agreement, dated as of July 22, 2013, by and between NRG Energy, Inc. and NRG Yield, Inc.	Incorporated herein by reference to Exhibit 10.5 to NRG Yield, Inc.'s Current Report on Form 8-K filed on July 26, 2013.
10.6	Loan Guarantee Agreement, dated as of September 30, 2011, by and among High Plains Ranch II, LLC, as borrower, the U.S. Department of Energy, as guarantor, and the U.S. Department of Energy, as loan servicer.	Incorporated herein by reference to Exhibit 10.8 to NRG Yield, Inc.'s Draft Registration Statement on Form S-1 filed on February 13, 2013.

120



10.7	Operation and Maintenance Agreement, dated as of January 31, 2011, by and between Avenal Solar Holdings LLC and NRG Energy Services LLC.	Incorporated herein by reference to Exhibit 10.11 to NRG Yield, Inc.'s Draft Registration Statement on Form S-1 filed on February 13, 2013.
10.8	Asset Management Agreement, dated as of August 30, 2012, by and between NRG Solar Avra Valley LLC and NRG Solar Asset Management LLC.	Incorporated herein by reference to Exhibit 10.12 to NRG Yield, Inc.'s Draft Registration Statement on Form S-1 filed on February 13, 2013.
10.9	Operation and Maintenance Agreement, dated as of August 1, 2012, by and between NRG Energy Services LLC and NRG Solar Borrego I LLC.	Incorporated herein by reference to Exhibit 10.13 to NRG Yield, Inc.'s Draft Registration Statement on Form S-1 filed on February 13, 2013.
10.10	Asset Management Agreement, dated as of March 15, 2012, by and between NRG Solar Alpine LLC and NRG Solar Asset Management LLC.	Incorporated herein by reference to Exhibit 10.14 to NRG Yield, Inc.'s Draft Registration Statement on Form S-1 filed on February 13, 2013.
10.11	Operation and Maintenance Agreement, dated as of September 30, 2011, by and between NRG Energy Services LLC and High Plains Ranch II, LLC.	Incorporated herein by reference to Exhibit 10.15 to NRG Yield, Inc.'s Draft Registration Statement on Form S-1 filed on February 13, 2013.
10.12	Project Administration Agreement, dated as of August 16, 2010, by and between South Trent Wind LLC and NRG Texas Power LLC.	Incorporated herein by reference to Exhibit 10.16 to NRG Yield, Inc.'s Draft Registration Statement on Form S-1 filed on February 13, 2013.
10.13	Operation and Maintenance Agreement, dated as of April 24, 2009, by and between GenConn Devon LLC and Devon Power LLC.	Incorporated herein by reference to Exhibit 10.15 to NRG Yield, Inc.'s Registration Statement on Form S-1 filed on June 6, 2013.
10.14	Operation and Maintenance Agreement, dated as of April 24, 2009, by and between GenConn Middletown LLC and Middletown Power LLC.	Incorporated herein by reference to Exhibit 10.16 to NRG Yield, Inc.'s Registration Statement on Form S-1 filed on June 7, 2013.
10.15	Administrative Services Agreement, dated as of April 2, 2009, by and between GenOn Energy Services, LLC (formerly Mirant Services, LLC) and NRG Marsh Landing, LLC (formerly Mirant Marsh Landing, LLC.	Incorporated herein by reference to Exhibit 10.17 to NRG Yield, Inc.'s Registration Statement on Form S-1 filed on June 7, 2013.
10.16	Form of Indemnification Agreement.	Incorporated herein by reference to Exhibit 10.20 to NRG Yield, Inc.'s Registration Statement on Form S-1/A filed on June 21, 2013.
10.17.1	Amended and Restated Credit Agreement, dated April 25, 2014, by and among NRG Yield Operating LLC, NRG Yield LLC, Royal Bank of Canada, as Administrative Agent, the lenders party thereto, Royal Bank of Canada, Goldman Sachs Bank USA and Bank of America, N.A., as L/C Issuers and RBC Capital Markets as Sole Left Lead Arranger and Sole Left Lead Book Runner.	Incorporated by reference to Exhibit 10.1 to NRG Yield, Inc.'s Current Report on Form 8-K filed on April 28, 2014.
10.17.2	First Amendment to Amended & Restated Credit Agreement, dated June 26, 2015, by and among NRG Yield Operating LLC, NRG Yield LLC, Royal Bank of Canada and the Lenders party thereto.	Incorporated herein by reference to Exhibit 10.9 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 4, 2015.
10.17.3	Second Amendment to Amended & Restated Credit Agreement, dated February 6, 2018, by and among NRG Yield Operating LLC, NRG Yield LLC, the guarantors party thereto, Royal Bank of Canada, as Administrative Agent, and the lenders party thereto.	Incorporated herein by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on February 12, 2018.
10.18.1	Credit Agreement, dated as of August 23, 2011, among NRG West Holdings LLC, ING Capital LLC, Union Bank, N.A., Mizuho Corporate Bank, Ltd., RBS Securities Inc., Credit Agricole Corporate and Investment Bank, and each of lenders and issuing banks thereto.*	Incorporated herein by reference to Exhibit 10.2 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 7, 2014.
10.18.2	Amendment No. 1 to the Credit Agreement, dated October 7, 2011, by and between NRG West Holdings LLC and Credit Agricole Corporate and Investment Bank.	Incorporated herein by reference to Exhibit 10.3 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 7, 2014.
10.18.3	Amendment No. 2 to the Credit Agreement, dated February 29, 2012, by and between NRG West Holdings LLC and Credit Agricole Corporate and Investment Bank.	Incorporated herein by reference to Exhibit 10.4 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 7, 2014.
10.18.4	Amendment No. 3 to the Credit Agreement, dated as of January 27, 2014, by and between NRG West Holdings LLC and Credit Agricole Corporate and Investment Bank.	Incorporated herein by reference to Exhibit 10.6 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 4, 2015.
10.18.5	Amendment No. 4 to the Credit Agreement and Amendment No. 1 to the Collateral Agreement, dated as of May 16, 2014, by and between NRG West Holdings LLC, El Segundo Energy Center LLC and Credit Agricole Corporate and Investment Bank.	Incorporated herein by reference to Exhibit 10.7 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 4, 2015.

121



10.18.6	Amendment No. 5 to the Credit Agreement, dated as of May 29, 2015, by and between NRG West Holdings LLC and ING Capital LLC.	Incorporated herein by reference to Exhibit 10.8 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 4, 2015.
10.19.1	Amended and Restated Credit Agreement, dated July 17, 2014, by and among NRG Marsh Landing LLC, The Royal Bank of Scotland Plc, Deutsche Bank Trust Company Americas and the lenders party thereto.	Incorporated herein by reference to Exhibit 10.5 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 7, 2014.
10.19.2	First Amendment to the Credit Agreement and Collateral Agency and Intercreditor Agreement, dated July 17, 2014, by and among NRG Marsh Landing LLC, The Royal Bank of Scotland Plc, Deutsche Bank Trust Company Americas and the lenders party thereto.	Incorporated herein by reference to Exhibit 10.6 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 7, 2014.
10.20^	Amended and Restated Limited Liability Company Agreement of NRG RPV Holdco 1 LLC, dated as of April 9, 2015.	Incorporated herein by reference to Exhibit 10.1 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 4, 2015.
10.21^	Amended and Restated Limited Liability Company Agreement of NRG DGPV Holdco 1 LLC, dated as of May 8, 2015.	Incorporated herein by reference to Exhibit 10.2 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on August 4, 2015.
10.22^	Amendment No. 1 to Amended and Restated Limited Liability Company Agreement of NRG RPV Holdco 1 LLC, dated as of March 1, 2016, by and between NRG Yield RPV Holding LLC and NRG Residential Solar Solutions LLC.	Incorporated herein by reference to Exhibit 10.1 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on May 5, 2016.
10.23^	Amendment No. 2 to Amended and Restated Limited Liability Company Agreement of NRG DGPV Holdco 1 LLC, dated as of March 1, 2016, by and among NRG Yield DGPV Holding LLC, NRG Renew DG Holdings LLC and NRG Renew LLC.	Incorporated herein by reference to Exhibit 10.2 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on May 5, 2016.
10.24^	Amended and Restated Limited Liability Company Agreement of NRG DGPV Holdco 2 LLC, dated as of March 1, 2016, by and among NRG Yield DGPV Holding LLC, NRG Renew DG Holdings LLC, and NRG Renew LLC.	Incorporated herein by reference to Exhibit 10.3 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q filed on May 5, 2016.
10.25	Amendment No. 2 to Amended and Restated Limited Liability Company Agreement of NRG RPV Holdco 1 LLC, dated as of August 5, 2016, by and between NRG Yield RPV Holding LLC and NRG Residential Solar Solutions LLC.	Incorporated herein by reference to Exhibit 10.1 to NRG Yield, Inc.'s Quarterly Report on Form 10-Q, filed on August 9, 2016.
10.26†	Employment Agreement, dated as of May 6, 2016, between NRG Yield, Inc. and Christopher S. Sotos.	Incorporated herein by reference to Exhibit 10.1 to NRG Yield, Inc.'s Current Report on Form 8-K/A, filed on August 9, 2016.
10.27†	Amendment, dated January 1, 2018 to Employment Agreement between NRG Yield, Inc. and Christopher Sotos.	Incorporated herein by reference to Exhibit 10.28 to NRG Yield, Inc.'s Annual Report on Form 10-K, filed on March 1, 2018.
10.28^	Consent and Indemnity Agreement, dated as of February 6, 2018, by and among NRG Energy, Inc., NRG Repowering Holdings LLC, NRG Yield, Inc., and GIP III Zephyr Acquisition Partners, L.P., and NRG Yield Operating LLC (solely with respect to Sections E.5, E.6 and G.12).	Incorporated herein by reference to Exhibit 10.34 to NRG Yield, Inc.'s Annual Report on Form 10-K, filed on March 1, 2018.
12.1	Computation of Ratio of Earnings to Fixed Charges.	Filed herewith.
21.1	Subsidiaries of NRG Yield LLC.	Filed herewith.
31.1	Rule 13a-14(a)/15d-14(a) certification of Christopher S. Sotos.	Filed herewith.
31.2	Rule 13a-14(a)/15d-14(a) certification of Chad Plotkin.	Filed herewith.
31.3	Rule 13a-14(a)/15d-14(a) certification of David Callen.	Filed herewith.
32	Section 1350 Certification.	Furnished 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.

122



†		Indicates exhibits that constitute compensatory plans or arrangements.
*		This filing excludes schedules pursuant to Item 601(b)(2) of Regulation S-K, which the registrant agrees to furnish supplementary to the Securities and Exchange Commission upon request by the Commission.
^		Portions of this exhibit have been redacted and are subject to a confidential treatment request filed with the Secretary of the Securities and Exchange Commission pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended.

123

Item 16 — Form 10-K Summary

None.

124

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 LLC (Registrant)

	/s/ CHRISTOPHER S. SOTOS
	Christopher S. Sotos
	Chief Executive Officer (Principal Executive Officer)

Date: March 1, 2018

POWER OF ATTORNEY

Each person whose signature appears below constitutes and appoints David R. Hill and Brian E. Curci, each or any of them, such person's true and lawful attorney-in-fact and agent with full power of substitution and resubstitution for such person and in such person's name, place and stead, in any and all capacities, to sign any and all amendments to this report on Form 10-K, and to file the same with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing necessary or desirable to be done in and about the premises, as fully to all intents and purposes as such person, hereby ratifying and confirming all that said attorneys-in-fact and agents, or any of them or his or their substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

In accordance with the Securities Exchange Act of 1934, this report has been signed by the following persons on behalf of the registrant in the capacities indicated on March 1, 2018.



	Signatures	Title
	/s/ CHRISTOPHER S. SOTOS	President and Chief Executive Officer
	Christopher S. Sotos	of NRG Yield LLC (Principal Executive Officer)
Date:	March 1, 2018

	/s/ CHAD PLOTKIN	Senior Vice President and Chief Financial Officer
	Chad Plotkin	of NRG Yield LLC (Principal Financial Officer)
Date:	March 1, 2018

	/s/ DAVID CALLEN	Senior Vice President and Chief Accounting Officer
	David Callen	of NRG Yield LLC (Principal Accounting Officer)
Date:	March 1, 2018

NRG YIELD, INC.		Sole Managing Member

	/s/ CHRISTOPHER S. SOTOS	President and Chief Executive Officer
	Christopher S. Sotos	of NRG Yield, Inc.
Date:	March 1, 2018

125



Signature	Title	Date

/s/ KIRKLAND B. ANDREWS	Director of NRG Yield, Inc.	March 1, 2018
Kirkland B. Andrews	Sole Managing Member of NRG Yield LLC	March 1, 2018

/s/ JOHN CHILLEMI	Director of NRG Yield, Inc.	March 1, 2018
John Chillemi	Sole Managing Member of NRG Yield LLC	March 1, 2018

/s/ JOHN CHLEBOWSKI	Director of NRG Yield, Inc.	March 1, 2018
John Chlebowski	Sole Managing Member of NRG Yield LLC	March 1, 2018

/s/ BRIAN FORD	Director of NRG Yield, Inc.	March 1, 2018
Brian Ford	Sole Managing Member of NRG Yield LLC	March 1, 2018

/s/ MAURICIO GUTIERREZ	Director of NRG Yield, Inc.	March 1, 2018
Mauricio Gutierrez	Sole Managing Member of NRG Yield LLC	March 1, 2018

/s/ FERRELL MCCLEAN	Director of NRG Yield, Inc.	March 1, 2018
Ferrell McClean	Sole Managing Member of NRG Yield LLC	March 1, 2018

/s/ CHRISTOPHER S. SOTOS	Director of NRG Yield, Inc.	March 1, 2018
Christopher S. Sotos	Sole Managing Member of NRG Yield LLC	March 1, 2018

126

Supplemental Information to be Furnished with Reports Filed Pursuant to
Section 15(d) of the Act by Registrants Which Have Not Registered
Securities Pursuant to Section 12 of the Act

No annual report or proxy materials has been sent to securities holders and no such report or proxy material is to be furnished to securities holders subsequent to the filing of the annual report on this Form 10-K.

127

Exhibit

EXHIBIT 12.1

NRG YIELD OPERATING LLC AND SUBSIDIARIES

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES



	For the Year Ended December 31,
	2017			2016^(b)			2015 ^(b)			2014^(b)			2013^(a)(b)
				(in millions, except ratio)
Earnings:
Income from continuing operations before income tax	$	61		$	17		$	95		$	123		$	149
Less:
Equity in earnings of unconsolidated affiliates	(71		)	(60		)	(31		)	(22		)	(27		)
Capitalized interest	—			—			—			—			(26		)
Add:
Fixed charges	300			277			261			220			100
Distributions from unconsolidated affiliates	72			58			60			21			15
Amortization of capitalized interest	3			3			3			3			2
Total Earnings:	$	365		$	295		$	388		$	345		$	213

Fixed Charges:
Interest expense	281			264			251			211			68
Capitalized interest	—			—			—			—			26
Amortization of debt issuance costs	13			8			7			6			5
Approximation of interest in rental expense	6			5			3			3			1
Total Fixed Charges:	$	300		$	277		$	261		$	220		$	100
Ratio of Earnings to Combined Fixed Charges	1.22			1.06			1.49			1.57			2.13

^(a)

For all periods prior to the Yield, Inc.'s initial public offering on July 22, 2013, the accompanying combined financial statements represent the combination of the assets that the Company acquired and were prepared using NRG's historical basis in the assets and liabilities. For the purposes of the combined financial statements, the term "NRG Yield Operating LLC and Subsidiaries" represents the accounting predecessor, or the combination of the acquired businesses. For all periods subsequent to the Yield Inc. initial public offering, the accompanying audited consolidated financial statements represent the consolidated results of the Company.


^(b)	Retrospectively adjusted as discussed in Item 15 — Note 1, Nature of Business, to the Consolidated Financial Statements.

Exhibit

EXHIBIT 21.1

SUBSIDIARIES OF NRG YIELD LLC



Entity Name	Jurisdiction
AC Solar Holdings LLC	Delaware
Adams Community Solar Garden I LLC	Colorado
Adams Community Solar Garden II LLC	Colorado
Adams Community Solar Garden III LLC	Colorado
Adams Community Solar Gardens LLC	Colorado
Agua Caliente Borrower 2 LLC	Delaware
Agua Caliente Solar Holdings LLC	Delaware
Agua Caliente Solar, LLC	Delaware
Alta Interconnection Management II, LLC	Delaware
Alta Interconnection Management III, LLC	Delaware
Alta Interconnection Management, LLC	Delaware
Alta Realty Holdings, LLC	Delaware
Alta Realty Investments, LLC	Delaware
Alta Wind 1-5 Holding Company, LLC	Delaware
Alta Wind Asset Management Holdings, LLC	Delaware
Alta Wind Asset Management, LLC	Delaware
Alta Wind Company, LLC	Delaware
Alta Wind Holdings, LLC	Delaware
Alta Wind I Holding Company, LLC	Delaware
Alta Wind I, LLC	Delaware
Alta Wind II Holding Company, LLC	Delaware
Alta Wind II, LLC	Delaware
Alta Wind III Holding Company, LLC	Delaware
Alta Wind III, LLC	Delaware
Alta Wind IV Holding Company, LLC	Delaware
Alta Wind IV, LLC	Delaware
Alta Wind V Holding Company, LLC	Delaware
Alta Wind V, LLC	Delaware
Alta Wind X Holding Company, LLC	Delaware
Alta Wind X, LLC	Delaware
Alta Wind XI Holding Company, LLC	Delaware
Alta Wind XI, LLC	Delaware
Alta Wind X-XI TE Holdco LLC	Delaware
Arapahoe Community Solar Garden I LLC	Colorado
Avenal Park LLC	Delaware
Avenal Solar Holdings LLC	Delaware
Bashaw Solar 1, LLC	Delaware
Big Lake Holdco LLC	Delaware
Black Cat Road Solar, LLC	Delaware
Brook Street Solar 1, LLC	Delaware
Buffalo Bear, LLC	Oklahoma



Bullock Road Solar 1, LLC	Delaware
BWC Swan Pond River, LLC	Delaware
Center St Solar 1, LLC	Delaware
Clear View Acres Wind Farm, LLC	Iowa
Colorado Shared Solar I LLC	Colorado
Colorado Springs Solar Garden LLC	Colorado
Continental Energy, LLC	Arizona
Crosswind Transmission, LLC	Iowa
CVSR Holdco LLC	Delaware
Cy-Hawk Wind Energy, LLC	Iowa
Denver Community Solar Garden I LLC	Colorado
Denver Community Solar Garden II LLC	Colorado
Desert Sunlight 250, LLC	Delaware
Desert Sunlight 300, LLC	Delaware
Desert Sunlight Holdings LLC	Delaware
Desert Sunlight Investment Holdings, LLC	Delaware
Dodge Holdco LLC	Delaware
Eagle View Acres Wind Farm, LLC	Iowa
El Mirage Energy, LLC	Arizona
El Segundo Energy Center LLC	Delaware
Elbow Creek Wind Project LLC	Texas
Elk Lake Wind Farm, LLC	Iowa
Elkhorn Ridge Wind, LLC	Delaware
Enterprise Solar, LLC	Delaware
Escalante Solar I, LLC	Delaware
Escalante Solar II, LLC	Delaware
Escalante Solar III, LLC	Delaware
Farmington Holdco LLC	Delaware
Federal Road Solar 1, LLC	Delaware
Forest Lake Holdco LLC	Delaware
Forward WindPower LLC	Delaware
Four Brothers Capital, LLC	Delaware
Four Brothers Holdings, LLC	Delaware
Four Brothers Portfolio, LLC	Delaware
Four Brothers Solar, LLC	Delaware
FUSD Energy, LLC	Arizona
GCE Holding LLC	Connecticut
GenConn Devon LLC	Connecticut
GenConn Energy LLC	Connecticut
GenConn Middletown LLC	Connecticut
Goat Wind LLC	Texas
Granite Mountain Capital, LLC	Delaware
Granite Mountain Holdings, LLC	Delaware
Granite Mountain Renewables, LLC	Delaware
Granite Mountain Solar East, LLC	Delaware
Granite Mountain Solar West, LLC	Delaware



Green Prairie Energy, LLC	Iowa
Greene Wind Energy, LLC	Iowa
Hardin Hilltop Wind, LLC	Iowa
Hardin Wind Energy, LLC	Iowa
High Plains Ranch II, LLC	Delaware
Highland Township Wind Farm, LLC	Iowa
HLE Solar Holdings, LLC	Delaware
HSD Solar Holdings, LLC	California
Hwy 14 Holdco LLC	Delaware
Iron Springs Capital, LLC	Delaware
Iron Springs Holdings, LLC	Delaware
Iron Springs Renewables, LLC	Delaware
Iron Springs Solar, LLC	Delaware
Laredo Ridge Wind, LLC	Delaware
Lenape II Solar LLC	Delaware
Lindberg Field Solar 1, LLC	Delaware
Lindberg Field Solar 2, LLC	Delaware
Longhorn Energy, LLC	Arizona
Lookout WindPower LLC	Delaware
MC1 Solar Farm, LLC	North Carolina
Mission Iowa Wind, LLC	California
Mission Minnesota Wind II, LLC	Delaware
Mission Wind Laredo, LLC	Delaware
Mission Wind New Mexico, LLC	Delaware
Mission Wind Oklahoma, LLC	Delaware
Mission Wind PA One, LLC	Delaware
Mission Wind PA Three, LLC	Delaware
Mission Wind PA Two, LLC	Delaware
Mission Wind Pennsylvania, LLC	Delaware
Mission Wind Utah, LLC	Delaware
Monster Energy, LLC	Arizona
Natural Gas Repowering LLC	Delaware
Northfield Holdco LLC	Delaware
NRG & EFS Distributed Solar 2 LLC	Delaware
NRG & EFS Distributed Solar LLC	Delaware
NRG 2011 Finance Holdco LLC	Delaware
NRG Alta Vista LLC	Delaware
NRG Apple I LLC	Delaware
NRG CA Fund LLC	Delaware
NRG Chestnut Borrower LLC	Delaware
NRG Chestnut Class B LLC	Delaware
NRG Chestnut Fund LLC	Delaware
NRG Chestnut Fund Sub LLC	Delaware
NRG DG Berkeley Rec LLC	Delaware
NRG DG Berkeley Village LLC	Delaware
NRG DG Central East LLC	Delaware



NRG DG Central West LLC	Delaware
NRG DG Contra Costa Operations LLC	Delaware
NRG DG Contra Costa Waste LLC	Delaware
NRG DG Crystal Spring LLC	Delaware
NRG DG Dighton LLC	Delaware
NRG DG Foxborough Elm LLC	Delaware
NRG DG Foxborough Landfill LLC	Delaware
NRG DG Grantland LLC	Delaware
NRG DG Haverhill LLC	Delaware
NRG DG Imperial Admin LLC	Delaware
NRG DG Imperial Building LLC	Delaware
NRG DG Lakeland LLC	Delaware
NRG DG Lathrop Louise LLC	Delaware
NRG DG Lincoln Middle LLC	Delaware
NRG DG Marathon LLC	Delaware
NRG DG Rosedale Elementary LLC	Delaware
NRG DG Rosedale Middle LLC	Delaware
NRG DG San Joaquin LLC	Delaware
NRG DG Tufts Knoll LLC	Delaware
NRG DG Tufts Science LLC	Delaware
NRG DG Washington Middle LLC	Delaware
NRG DG Webster LLC	Delaware
NRG DGPV 1 LLC	Delaware
NRG DGPV 2 LLC	Delaware
NRG DGPV 3 LLC	Delaware
NRG DGPV 4 Borrower LLC	Delaware
NRG DGPV 4 LLC	Delaware
NRG DGPV Fund 1 LLC	Delaware
NRG DGPV Fund 2 HoldCo A LLC	Delaware
NRG DGPV Fund 2 HoldCo B LLC	Delaware
NRG DGPV Fund 2 LLC	Delaware
NRG DGPV Fund 4 LLC	Delaware
NRG DGPV Fund 4 Sub LLC	Delaware
NRG DGPV HoldCo 1 LLC	Delaware
NRG DGPV HoldCo 2 LLC	Delaware
NRG DGPV HoldCo 3 LLC	Delaware
NRG Electricity Sales Princeton LLC	Delaware
NRG Elkhorn Holdings LLC	Delaware
NRG Energy Center Dover LLC	Delaware
NRG Energy Center Harrisburg LLC	Delaware
NRG Energy Center HCEC LLC	Delaware
NRG Energy Center Minneapolis LLC	Delaware
NRG Energy Center Omaha Holdings LLC	Delaware
NRG Energy Center Omaha LLC	Delaware
NRG Energy Center Paxton LLC	Delaware
NRG Energy Center Phoenix LLC	Delaware



NRG Energy Center Pittsburgh LLC	Delaware
NRG Energy Center Princeton LLC	Delaware
NRG Energy Center San Diego LLC	Delaware
NRG Energy Center San Francisco LLC	Delaware
NRG Energy Center Smyrna LLC	Delaware
NRG Energy Center Tucson LLC	Arizona
NRG Golden Puma Fund LLC	Delaware
NRG Golden Puma Revolve LLC	Delaware
NRG Harrisburg Cooling LLC	Delaware
NRG Huntington Beach LLC	Delaware
NRG Marsh Landing Holdings LLC	Delaware
NRG Marsh Landing LLC	Delaware
NRG PC Dinuba LLC	Delaware
NRG Puma Class B LLC	Delaware
NRG Renew Canal 1 LLC	Delaware
NRG Renew Spark 2 LLC	Delaware
NRG RPV 1 LLC	Delaware
NRG RPV 2 LLC	Delaware
NRG RPV Fund 11 LLC	Delaware
NRG RPV Fund 12 LLC	Delaware
NRG RPV Fund 13 LLC	Delaware
NRG RPV HoldCo 1 LLC	Delaware
NRG Solar Alpine LLC	Delaware
NRG Solar Apple LLC	Delaware
NRG Solar AV Holdco LLC	Delaware
NRG Solar Avra Valley LLC	Delaware
NRG Solar Blythe II LLC	Delaware
NRG Solar Blythe LLC	Delaware
NRG Solar Borrego Holdco LLC	Delaware
NRG Solar Borrego I LLC	Delaware
NRG Solar Community 1 LLC	Delaware
NRG Solar Community Holdco LLC	Delaware
NRG Solar CVSR Holdings LLC	Delaware
NRG Solar Iguana LLC	Delaware
NRG Solar Kansas South Holdings LLC	Delaware
NRG Solar Kansas South LLC	Delaware
NRG Solar Las Vegas MB 1 LLC	Delaware
NRG Solar Las Vegas MB 2 LLC	Delaware
NRG Solar Mayfair LLC	Delaware
NRG Solar Mule LLC	Delaware
NRG Solar Oasis LLC	Delaware
NRG Solar Roadrunner Holdings LLC	Delaware
NRG Solar Roadrunner LLC	Delaware
NRG Solar Star LLC	Delaware
NRG Solar Tabernacle LLC	Delaware
NRG Solar Warren LLC	Delaware



NRG Solar Wauwinet LLC	Delaware
NRG Solar West Shaft LLC	Delaware
NRG South Trent Holdings LLC	Delaware
NRG Thermal LLC	Delaware
NRG Walnut Creek II LLC	Delaware
NRG Walnut Creek LLC	Delaware
NRG West Holdings LLC	Delaware
NRG Wind TE Holdco LLC	Delaware
NRG Yield AC Solar Holdings LLC	Delaware
NRG Yield CVSR Holdings LLC	Delaware
NRG Yield DGPV Holding LLC	Delaware
NRG Yield Operating LLC	Delaware
NRG Yield RPV Holding LLC	Delaware
NRG Yield Utah Solar Holdings LLC	Delaware
NS Smith, LLC	Delaware
NYLD Fuel Cell Holdings LLC	Delaware
OC Solar 2010, LLC	California
Odin Wind Farm LLC	Minnesota
Old Westminster Solar 1, LLC	Delaware
Old Westminster Solar 2, LLC	Delaware
OWF Eight, LLC	Minnesota
OWF Five, LLC	Minnesota
OWF Four, LLC	Minnesota
OWF One, LLC	Minnesota
OWF Seven, LLC	Minnesota
OWF Six, LLC	Minnesota
OWF Three, LLC	Minnesota
OWF Two, LLC	Minnesota
Palo Alto County Wind Farm, LLC	Iowa
PESD Energy, LLC	Arizona
Pikes Peak Solar Garden I LLC	Colorado
Pine Island Holdco LLC	Delaware
Pinnacle Wind, LLC	Delaware
PM Solar Holdings, LLC	California
Pond Road Solar, LLC	Delaware
Portfolio Solar I, LLC	Delaware
Poverty Ridge Wind, LLC	Iowa
Redbrook Solar 1, LLC	Delaware
San Juan Mesa Investments, LLC	Delaware
San Juan Mesa Wind Project, LLC	Delaware
Sand Drag LLC	Delaware
SCDA Solar 1, LLC	Delaware
SCWFD Energy, LLC	Arizona
Silver Lake Acres Wind Farm, LLC	Iowa
SJA Solar LLC	Delaware
Sleeping Bear, LLC	Delaware



Solar Flagstaff One LLC	Delaware
South Trent Wind LLC	Delaware
Spanish Fork Wind Park 2, LLC	Utah
SPP Asset Holdings, LLC	Delaware
SPP Fund II Holdings, LLC	Delaware
SPP Fund II, LLC	Delaware
SPP Fund II-B, LLC	Delaware
SPP Fund III, LLC	Delaware
SPP Lease Holdings, LLC	Delaware
SPP P-IV Master Lessee, LLC	Delaware
Spring Canyon Energy II LLC	Delaware
Spring Canyon Energy III LLC	Delaware
Spring Canyon Expansion Class B Holdings LLC	Delaware
Spring Canyon Expansion Holdings LLC	Delaware
Spring Canyon Expansion LLC	Delaware
Spring Canyon Interconnection LLC	Delaware
Spring Street Solar 1, LLC	Delaware
Stafford St Solar 1, LLC	Delaware
Stafford St Solar 2, LLC	Delaware
Stafford St Solar 3, LLC	Delaware
Statoil Energy Power/Pennsylvania, Inc.	Pennsylvania
Steel Bridge Solar, LLC	Delaware
Sun City Project LLC	Delaware
Sunrise View Wind Farm, LLC	Iowa
Sunset View Wind Farm, LLC	Iowa
Sutton Wind Energy, LLC	Iowa
TA - High Desert, LLC	California
Taloga Wind, L.L.C.	Oklahoma
Tapestry Wind, LLC	Delaware
Topeka Solar 1, LLC	Delaware
TOS Solar 1, LLC	Delaware
TOS Solar 2, LLC	Delaware
TOS Solar 4, LLC	Delaware
TOS Solar 5, LLC	Delaware
Tully Farms Solar 1, LLC	Delaware
UB Fuel Cell, LLC	Connecticut
Vail Energy, LLC	Arizona
Viento Funding II, LLC	Delaware
Viento Funding, LLC	Delaware
Virgin Lake Wind Farm, LLC	Iowa
Wabasha Holdco LLC	Delaware
Walnut Creek Energy, LLC	Delaware
Waterford Holdco LLC	Delaware
WCEP Holdings, LLC	Delaware
Webster Holdco LLC	Delaware
Wildcat Energy, LLC	Arizona



Wildorado Interconnect, LLC	Texas
Wildorado Wind, LLC	Texas
Wind Family Turbine, LLC	Iowa
WSD Solar Holdings, LLC	Delaware
Zontos Wind, LLC	Iowa

Exhibit

EXHIBIT 31.1

CERTIFICATION

I, Christopher S. Sotos, certify that:


1.	I have reviewed this annual report on Form 10-K of NRG Yield LLC;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.	The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):


(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.



/s/ CHRISTOPHER S. SOTOS
Christopher S. Sotos Chief Executive Officer (Principal Executive Officer)

Date: March 1, 2018

Exhibit

EXHIBIT 31.2

CERTIFICATION

I, Chad Plotkin, certify that:


1.	I have reviewed this annual report on Form 10-K of NRG Yield LLC;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.	The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):


(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.



/s/ CHAD PLOTKIN
Chad Plotkin Chief Financial Officer (Principal Financial Officer)

Date: March 1, 2018

Exhibit

EXHIBIT 31.3

CERTIFICATION

I, David Callen, certify that:


1.	I have reviewed this annual report on Form 10-K of NRG Yield LLC;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.	The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):


(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.



/s/ DAVID CALLEN
David Callen Chief Accounting Officer (Principal Accounting Officer)

Date: March 1, 2018

Exhibit

EXHIBIT 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report of NRG Yield LLC on Form 10-K for the year ended December 31, 2017, as filed with the Securities and Exchange Commission on the date hereof (the “Form 10-K”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer's knowledge:


(1)	The Form 10-K fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and


(2)	The information contained in the Form 10-K fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods expressed in the Form 10-K.

Date: March 1, 2018



	/s/ CHRISTOPHER S. SOTOS
	Christopher S. Sotos
	Chief Executive Officer (Principal Executive Officer)


	/s/ CHAD PLOTKIN
	Chad Plotkin
	Chief Financial Officer (Principal Financial Officer)


	/s/ DAVID CALLEN
	David Callen
	Chief Accounting Officer (Principal Accounting Officer)

The foregoing certification is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of this Form 10-K or as a separate disclosure document.

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to NRG Yield LLC and will be retained by NRG Yield LLC and furnished to the Securities and Exchange Commission or its staff upon request.