UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 8-K

CURRENT REPORT
Pursuant to Section 13 OR 15(d) of The Securities Exchange Act of 1934

 	 	
 	Date of Report (Date of earliest event reported):  May 22, 2015	
NRG YIELD, INC.
(Exact name of Registrant as specified in its charter)

 	 	 	
Delaware
(State or other jurisdiction of incorporation)	001-36002
(Commission File Number)	46-1777204
(I.R.S. Employer Identification No.)	
 	 	 	
211 Carnegie Center, Princeton, New Jersey 08540
(Address of principal executive offices, including zip code)	

(609) 524-4500
(Registrant's telephone number, including area code)
N/A
(Former name or former address, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
o           Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
o           Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
o           Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
o            Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

 	

Item 8.01 Other Events.
On January 2, 2015, NRG Yield Operating LLC, a subsidiary of NRG Yield, Inc. (the "Company"), completed its acquisition of (i) 100% of the membership interests of Mission Wind Laredo, LLC, which indirectly owns Laredo Ridge, an 81 MW wind facility located in Petersburg, Nebraska, from NRG Wind LLC (“ NRG Wind ”), (ii) 100% of the membership interests of Tapestry Wind LLC, which indirectly owns three wind facilities totaling 204 MW, including Buffalo Bear, a 19 MW wind facility in Oklahoma; Taloga, a 130 MW wind facility in Oklahoma; and Pinnacle, a 55 MW wind facility in West Virginia, from NRG Wind, and (iii) 100% of the membership interests of WCEP Holdings, LLC, which indirectly owns Walnut Creek, a 485 MW natural gas facility located in City of Industry, California, from NRG Arroyo Nogales LLC (“ NRG Arroyo Nogales ” and, together with NRG Wind, the “ Sellers ”) (collectively, the “ Drop-Down Transaction ”), pursuant to those certain purchase and sale agreements with the Sellers, each of which are wholly-owned subsidiaries of NRG Energy, Inc.

In addition, on May 14, 2015, the Company completed its previously approved stock split, whereby (i) each outstanding share of the Company’s Class A common stock was split into one share of Class A common stock and one share of Class C common stock and (ii) each outstanding share of Class B common stock was split into one share of Class B common stock and one share of Class D common stock (the “ Stock Split ”).

The Company is filing this Current Report on Form 8-K to revise its audited historical consolidated financial statements as of December 31, 2014 and 2013 and for each of the years ended December 31, 2014, 2013 and 2012, to (i) reflect the retrospective effect of the Drop-Down Transaction, which is an acquisition accounted for as a transfer of entities under common control, completed by the Company subsequent to the Company’s most recent fiscal year, which was significant pursuant to Rule 11-01(b) of Regulation S-X and (ii) reflect the Stock Split. Exhibits 99.1, 99.2 and 99.3 included in this Current Report on Form 8-K give retrospective effect to the Drop-Down Transaction and the Stock Split.

The Company's Annual Report on Form 10-K for the year ended December 31, 2014 (the "2014 Form 10-K") is hereby recast by this Current Report on Form 8-K as follows:
 	 	
•	the Selected Financial Data of the Company included herein on Exhibit 99.1 supersedes Part II, Item 6 of the 2014 Form 10-K;	
 	 	
•	the Management's Discussion and Analysis of Financial Condition and Results of Operations of the Company included herein on Exhibit 99.2 supersedes Part II, Item 7 of the 2014 Form 10-K; and	
 	 	
•	the consolidated financial statements and financial statement schedule of the Company included herein on Exhibit 99.3 supersedes Part IV, Item 15 of the 2014 Form 10-K, except for (i) the GCE Holding LLC unaudited consolidated financial statements for the years ended December 31, 2014 and 2013 and the GCE Holding LLC audited consolidated financial statements for the year ended December 31, 2012, included on pages 111-135 of the Company's 2014 Form 10-K, pursuant to the requirements of Rule 3-09 of Regulation S-X, and (ii) the exhibit index, both of which are not impacted by this Current Report on Form 8-K.	
 
There have been no revisions or updates to any other sections of the 2014 Form 10-K other than the revisions noted above. This Current Report on Form 8-K should be read in conjunction with the 2014 Form 10-K, and any references herein to Items 6 and 7 under Part II and Item 15 of Part IV of the 2014 Form 10-K refer to Exhibits 99.1, 99.2, and 99.3, respectively. As of the date of this Current Report on Form 8-K, future references to the Company’s audited historical consolidated financial statements should be made to this Current Report on Form 8-K as well as future quarterly and annual reports on Forms 10-Q and Form 10-K, respectively.

Item 9.01 Financial Statements and Exhibits.

(d) Exhibits

The Exhibit Index attached to this Form 8-K is incorporated by reference herein.

2

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 hereunto duly authorized.

 	 	 	 	 	
 	NRG Yield, Inc.
(Registrant)	 	
 	By:	/s/ Brian E. Curci	 	
 	 	Brian E. Curci	 	
 	 	Corporate Secretary	 	

Dated: May 22, 2015

3

EXHIBIT INDEX

Exhibit No.	 	Document	
23.1	 	Consent of KPMG LLP.	
99.1	 	Selected Financial Data.	
99.2	 	Management's Discussion and Analysis of Financial Condition and Results of Operations.	
99.3	 	Consolidated Financial Statements and Financial Statement Schedule.	
101 INS	 	XBRL Instance Document.	
101 SCH	 	XBRL Taxonomy Extension Schema.	
101 CAL	 	XBRL Taxonomy Extension Calculation Linkbase.	
101 DEF	 	XRBL Taxonomy Extension Definition Linkbase.	
101 LAB	 	XBRL Taxonomy Extension Label Linkbase.	
101 PRE	 	XBRL Taxonomy Extension Presentation Linkbase.	

4

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm
The Board of Directors
NRG Yield, Inc.:

We consent to the incorporation by reference in the registration statement (No. 333‑190071) on Form S-8 and registration statement (No. 333-201594) on Form S-3 of NRG Yield, Inc. of our report dated May 22, 2015, with respect to the consolidated balance sheets of NRG Yield, Inc. as of December 31, 2014 and 2013, and the related consolidated statements of operations, stockholders’ equity, cash flows, and comprehensive income for each of the years in the three-year period ended December 31, 2014, which report appears in the Current Report on Form 8-K of NRG Yield, Inc. dated May 22, 2015.

/s/ KPMG LLP

Philadelphia, Pennsylvania
May 22, 2015

Exhibit 99.1                

Item 6 — Selected Financial Data
The following table presents the Company's historical selected financial data, which has been recast to include the Acquired ROFO and EME-NYLD-Eligible Assets, or collectively, the Drop Down Assets, as if the transfers had taken place from the beginning of the financial statements period, or from the date the entities were under common control. The acquisitions are further described in  Item  —  15, Note 3,  Business Acquisitions . The table also shows the retrospective effect of the stock split, which is further described in Item —  15, Note 11,  Stockholders' Equity.  Additionally, for all periods prior to the initial public offering, 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 NRG Yield LLC on July 22, 2013. For all periods subsequent to the initial public offering, 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, except per share data)	2014	 	2013	 	2012	 	2011	 	2010	
Statement of Income Data:	 	 	 	
Operating Revenues	 	 	 	 	 	 	 	 	 	
Total operating revenues	$	689	
 	 	$	379	
 	 	$	175	
 	 	$	164	
 	 	$	143	
 	
Operating Costs and Expenses	 	 	 	 	 	 	 	 	 	
Cost of operations	239	
 	 	144	
 	 	114	
 	 	109	
 	 	102	
 	
Depreciation and amortization	166	
 	 	61	
 	 	25	
 	 	22	
 	 	16	
 	
General and administrative — affiliate	8	
 	 	7	
 	 	7	
 	 	6	
 	 	5	
 	
Acquisition-related transaction and integration costs	4	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	
Total operating costs and expenses	417	
 	 	212	
 	 	146	
 	 	137	
 	 	123	
 	
Operating Income	272	
 	 	167	
 	 	29	
 	 	27	
 	 	20	
 	
Other Income (Expense)	 	 	 	 	 	 	 	 	 	
Equity in earnings of unconsolidated affiliates	27	
 	 	22	
 	 	19	
 	 	13	
 	 	1	
 	
Other income, net	3	
 	 	3	
 	 	2	
 	 	2	
 	 	3	
 	
Interest expense	(186	)	 	(52	)	 	(28	)	 	(19	)	 	(13	)	
Total other expense	(156	)	 	(27	)	 	(7	)	 	(4	)	 	(9	)	
Income Before Income Taxes	116	
 	 	140	
 	 	22	
 	 	23	
 	 	11	
 	
Income tax expense	4	
 	 	8	
 	 	10	
 	 	9	
 	 	4	
 	
Net Income	$	112	
 	 	$	132	
 	 	$	12	
 	 	$	14	
 	 	$	7	
 	
Less: Pre-acquisition net income of Drop Down Assets	48	
 	 	23	
 	 	 	 	 	 	 	
Net Income Excluding Pre-acquisition Net Income of Drop Down Assets	64	
 	 	109	

 	 	 	
Less: Predecessor income prior to initial public offering on July 22, 2013	—	
 	 	54	
 	 	 	 	 	 	 	
Less: Net income attributable to NRG	48	
 	 	42	
 	 	 	 	 	 	 	
Net Income Attributable to NRG Yield, Inc.	$	16	
 	 	$	13	
 	 	 	 	 	 	 	
Earnings Per Share Attributable to NRG Yield, Inc. Class A and Class C Common Stockholders	 	 	 	 	 	 	 	 	 	
Earnings per Weighted Average Class A Common Share - Basic and Diluted	$	0.30	
 	 	$	0.29	
 	 	n/a	
 	 	n/a	
 	 	n/a	
 	
Earnings per Weighted Average Class C Common Share - Basic and Diluted	$	0.30	
 	 	$	0.29	
 	 	n/a	
 	 	n/a	
 	 	n/a	
 	
Dividends per Class A common share (a)	$	1.42	
 	 	$	0.23	
 	 	n/a	
 	 	n/a	
 	 	n/a	
 	
Other Financial Data:	 	 	 	 	 	 	 	 	 	
  Capital expenditures	33	
 	 	353	
 	 	564	
 	 	373	
 	 	65	
 	
Cash Flow Data:	 	 	 	 	 	 	 	 	 	
  Net cash provided by (used in):	 	 	 	 	 	 	 	 	 	
    Operating activities	$	293	
 	 	$	120	
 	 	$	56	
 	 	$	32	
 	 	$	36	
 	
    Investing activities	(1,057	)	 	(515	)	 	(594	)	 	(468	)	 	(200	)	
    Financing activities	1,111	
 	 	432	
 	 	536	
 	 	427	
 	 	180	
 	
Balance Sheet Data (at period end):	 	 	 	 	 	 	 	 	 	
  Cash and cash equivalents	$	406	
 	 	$	59	
 	 	$	22	
 	 	$	24	
 	 	$	33	
 	
  Property, plant and equipment, net	4,466	
 	 	2,291	
 	 	2,130	
 	 	863	
 	 	526	
 	
  Total assets	6,965	
 	 	3,238	
 	 	2,540	
 	 	1,239	
 	 	784	
 	
  Total liabilities	5,080	
 	 	1,986	
 	 	1,538	
 	 	678	
 	 	592	
 	
  Total stockholders' equity	1,885	
 	 	1,252	
 	 	1,002	
 	 	561	
 	 	192	
 	
(a) Dividends on Class A common shares began after the initial public offering on July 22, 2013.	 	 	 	 	 	 	 	 	 	

2

Exhibit 99.2        

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. For all periods prior to the initial public offering, the discussion 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 NRG Yield LLC on July 22, 2013. For all periods subsequent to the initial public offering, the discussion reflects the Company's consolidated financial results. In addition, as discussed in Item 15 — Note 1,  Nature of Business  to this Form 8-K, the acquisitions of the Acquired ROFO Assets and EME-NYLD-Eligible Assets on June 30, 2014 and January 2, 2015, respectively, or collectively, the Drop Down Assets, were accounted for in accordance with  ASC 850-50, 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 NRG and reduced the balance of its noncontrolling interest. The guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control.
As you read this discussion and analysis, refer to the recast Company's Consolidated Statements of Operations to this Form 8-K, which present the results of operations for the years ended December 31, 2014, 2013 and 2012. Also refer to Item 1 -  Business , to the Company's 2014 Form 10-K which includes detailed discussions of various items impacting the Company's business, results of operations and financial condition.
The discussion and analysis below has been organized as follows:
 	 	
•	Executive Summary, including a description of the business and significant events that are important to understanding the results of operations and financial condition;	
 	 	
•	Results of operations, including an explanation of significant differences between the periods in the specific line items of the consolidated statements of operations;	
 	 	
•	Financial condition addressing liquidity position, sources and uses of cash, capital resources and requirements, commitments, and off-balance sheet arrangements;	
 	 	
•	Known trends that may affect the Company’s results of operations and financial condition in the future; and	
 	 	
•	Critical accounting policies which are most important to both the portrayal of the Company's financial condition and results of operations, and which require management's most difficult, subjective or complex judgment.	

1

Executive Summary
Introduction and Overview
The Company is a dividend growth-oriented company formed to serve as the primary vehicle through which NRG owns, operates and acquires contracted renewable and conventional generation and thermal infrastructure assets. The Company believes it is well positioned to be a premier company for investors seeking stable and growing dividend income from a diversified portfolio of lower-risk high-quality assets.
The Company owns a diversified portfolio of contracted renewable and conventional generation and thermal infrastructure assets in the United States. The Company’s contracted generation portfolio collectively represents  3,630 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  18 years as of  December 31, 2014 based on cash available for distribution . The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,310 net MWt and electric generation capacity of 124 net MW. These thermal infrastructure assets provide steam, hot water and/or chilled water, and in some instances electricity, to commercial businesses, universities, hospitals and governmental units in multiple locations, principally through long-term contracts or pursuant to rates regulated by state utility commissions.
Government Incentives
Government incentives can enhance the economics of the Company's generating assets or investments by providing, for example, loan guarantees, cash grants, favorable tax treatment, favorable depreciation rules, or other incentives.  Certain recent proposals enhance federal incentives for renewable generation — including through the permanent extension of the wind power Production Tax Credit and the extension of the solar Investment Tax Credit, and could incentivize the development of additional renewable energy projects that would fit within the Company’s asset portfolio.  In addition, direct cash incentives may encourage additional renewable energy development by non-taxpaying entities that cannot always take advantage of tax credits.

Significant Events During the Twelve Months Ended December 31, 2014 

Alta Wind Portfolio Acquisition
On August 12, 2014, the Company acquired 100% of the membership interests of Alta Wind Asset Management Holdings, LLC, Alta Wind Company, LLC, Alta Wind X Holding Company, LLC and Alta Wind XI Holding Company, LLC, which collectively own seven wind facilities that total 947 MW located in Tehachapi, California, and a portfolio of associated land leases, or the Alta Wind Portfolio. The purchase price for the Alta Wind Portfolio was $923 million, which included a base purchase price of $870 million, and a payment for working capital of $53 million, plus the assumption of $1.6 billion of non-recourse project-level debt. Terra-Gen, an affiliate of the Alta Sellers, provides the day-to-day operations and maintenance services under a 10-year O&M agreement, which will automatically extend for additional five-year periods unless either party provides notice of termination at least 90 days prior to the expiration of the then-current term. Pursuant to the terms of such agreement, Terra-Gen is paid a fixed monthly payment (adjusted annually for inflation) and reimbursed for certain costs incurred. In order to fund the purchase price, the Company completed an equity offering of 12,075,000 shares of its Class A common stock at an offering price of $54.00 per share on July 29, 2014, which resulted in net proceeds of $630 million, after underwriting discounts and expenses. In addition, on August 5, 2014, NRG Yield Operating LLC issued $500 million of Senior Notes, as described in Item 15 — Note 9,  Long-term Debt.
Acquisition of Acquired ROFO Assets from NRG
On June 30, 2014, the Company acquired from NRG: (i) El Segundo, a 550 MW fast-start, gas-fired facility located in Los Angeles County, California; (ii) TA High Desert, a 20 MW solar facility located in Los Angeles County, California; and (iii) RE Kansas South, a 20 MW solar facility located in Kings County, California. The assets were acquired pursuant to the ROFO Agreement. The Company paid NRG total cash consideration of $357 million, which represents a base purchase price of $349 million and a payment for working capital of $8 million. In addition, the acquisition included the assumption of $612 million in project-level debt.

2

Issuance of 3.50% Convertible Notes
During the first quarter of 2014, the Company issued $345 million in aggregate principal amount of its convertible notes as described in Item 15 — Note 9,  Long-term Debt .
Significant Events During the Twelve Months Ended December 31, 2013 
On December 31, 2013, NRG Energy Center Omaha Holdings, LLC, an indirect wholly owned subsidiary of NRG Yield LLC, acquired Energy Systems Company, or Energy Systems, an operator of steam and chilled thermal facilities that provides heating and cooling services to nonresidential customers in Omaha, Nebraska.  See Item 15  —  Note 3,  Business Acquisitions , for information related to the acquisition.
During 2013, Alpine, Avra, Borrego, CVSR, El Segundo, Marsh Landing, RE Kansas South, and TA High Desert achieved COD. In addition, Borrego completed financing arrangements with a group of lenders. See Item 15  —  Note 9,  Long-term Debt , for information related to these financing activities. The Company completed its initial public offering of its Class A common stock on July 22, 2013. See Item 15  —  Note 1,  Nature of Business , for information related to the initial public offering.
Significant Events During the Twelve Months Ended December 31, 2012 
During 2012, Alpine completed a financing arrangement with a group of lenders. See Item 15 — Note 9, Long-term Debt  for information related to this financing activity.
Environmental Matters and Regulatory Matters
Details of environmental matters are presented in Item 15 — Note 16, Environmental Matters. Details of regulatory matters are presented in Item 1—  Business, Regulatory Matters . Details of some of this information relate to costs that may be material to the Company's financial results.
Basis of Presentation
For all periods prior to the Company's initial public offering, the accompanying combined financial statements represent the combination of the assets that NRG Yield LLC 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" represents the accounting predecessor, or the combination of the acquired businesses. For all periods subsequent to the initial public offering, the accompanying consolidated financial statements represent the consolidated results of NRG Yield, Inc., which consolidates NRG Yield LLC through its controlling interest.
The acquisitions of the TA High Desert, RE Kansas South, and El Segundo projects from NRG on June 30, 2014, and the Laredo Ridge, Tapestry, and Walnut Creek projects on January 2, 2015, were accounted for as transfers of entities under common control. The guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. Accordingly, the Company prepared its consolidated financial statements to reflect the transfers as if they took place on January 1, 2012, or from the date the entities were under common control, which was May 13, 2013, for RE Kansas South, March 28, 2013, for TA High Desert, and April 1, 2014, for the Laredo Ridge, Tapestry, and Walnut Creek projects. Members' equity represents NRG's equity in the subsidiaries, and accordingly, in connection with their acquisition by the Company, the balance was reclassified to noncontrolling interest. The Company reduces net income attributable to its Class A and Class C common stockholders by the pre-acquisition net income for the Drop Down Assets as it is not available to the stockholders.

3

Consolidated Results of Operations
2014 compared to 2013 
The following table provides selected financial information:

 	Year ended December 31,	
(In millions, except otherwise noted)	2014	 	2013	 	Change %	
Operating Revenues	 	 	 	 	 	
Total operating revenues	$	689	
 	 	$	379	
 	 	82	
 	
Operating Costs and Expenses	 	 	 	 	 	
Cost of operations	239	
 	 	144	
 	 	66	
 	
Depreciation and amortization	166	
 	 	61	
 	 	172	
 	
General and administrative — affiliate	8	
 	 	7	
 	 	14	
 	
Acquisition-related transaction and integration costs	4	
 	 	—	
 	 	100	
 	
Total operating costs and expenses	417	
 	 	212	
 	 	97	
 	
Operating Income	272	
 	 	167	
 	 	63	
 	
Other Income (Expense)	 	 	 	 	
 	
Equity in earnings of unconsolidated affiliates	27	
 	 	22	
 	 	23	
 	
Other income, net	3	
 	 	3	
 	 	—	
 	
Interest expense	(186	)	 	(52	)	 	258	
 	
Total other expense	(156	)	 	(27	)	 	478	
 	
Income Before Income Taxes	116	
 	 	140	
 	 	(17	)	
Income tax expense	4	
 	 	8	
 	 	(50	)	
Net Income	112	
 	 	132	
 	 	(15	)	
Less: Pre-acquisition net income of Drop Down Assets	48	
 	 	23	
 	 	109	
 	
Net Income Excluding Pre-acquisition Net Income of Drop Down Assets	64	
 	 	109	
 	 	(41	)	
Less: Predecessor income prior to initial public offering on July 22, 2013	—	
 	 	54	
 	 	(100	)	
Less: Net income attributable to NRG	48	
 	 	42	
 	 	14	
 	
Net Income Attributable to NRG Yield, Inc.	$	16	
 	 	$	13	
 	 	23	

 	
 	 	 	 	 	 	
 	Year ended December 31,	
Business metrics:	2014 (a)	 	2013 (a)	
Renewable MWh sold (in thousands)	2,313	
 	 	854	
 	
Thermal MWt sold (in thousands)	2,060	
 	 	1,679	
 	
(a) Volumes sold do not include MWh of 205 thousand and 139 thousand for thermal generation for the years ended December 31, 2014, and 2013, respectively.

4

Management’s discussion of the results of operations for the years ended December 31, 2014 and 2013
Operating Revenues

 	Conventional	 	Renewables	 	Thermal	 	Total	
(In millions)	 	
Year ended December 31, 2014	$	317	
 	 	$	177	
 	 	$	195	
 	 	$	689	
 	
Year ended December 31, 2013	138	
 	 	89	
 	 	152	
 	 	379	
 	
Operating revenuesincreased by $310 million during the twelve months ended December 31, 2014, compared to the same period in 2013 due to:

Increase in Conventional revenues as El Segundo and Marsh Landing reached commercial operations in 2013, as well as the acquisition of Walnut Creek, which was acquired by NRG on April 1, 2014 and sold to the Company on January 2, 2015	$	179	
 	
Increase due to acquisition of Alta Wind Portfolio in August 2014	49	
 	
Increase in Thermal revenues generated from Energy Systems acquired in the fourth quarter of 2013, repowering of Dover facilities in the second quarter of 2013, as well as increased generation at other Thermal facilities due to weather conditions in the first quarter of 2014	43	
 	
Increase in Renewables revenue generated by the Tapestry and Laredo Ridge projects, which were acquired by NRG on April 1, 2014 and sold to the Company on January 2, 2015, as well as the RE Kansas South, TA High Desert, and Borrego facilities, which reached commercial operations in the first half of 2013	39	
 	
 	$	310	
 	
Cost of Operations

 	Conventional	 	Renewables	 	Thermal	 	Total	
(In millions)	 	
Year ended December 31, 2014	$	55	
 	 	$	45	
 	 	$	139	
 	 	$	239	
 	
Year ended December 31, 2013	23	
 	 	11	
 	 	110	
 	 	144	
 	
Cost of operations increased by $95 million during the year ended December 31, 2014, compared to the same period in 2013 due to:

Increased costs in connection with the Energy Systems acquisition, higher cost of production due to repowering of Dover facilities in the second quarter of 2013, as well as increased generation at other Thermal facilities due to weather conditions in the first quarter of 2014	$	29	
 	
Increase due to acquisition of Alta Wind Portfolio in August 2014	20	
 	
Increase in costs associated with maintenance and operations at Marsh Landing and El Segundo which reached commercial operations in 2013, as well as Walnut Creek, which was acquired by NRG on April 1, 2014, and sold to the Company on January 2, 2015	32	
 	
Increase in costs due to the acquisition of the Tapestry and Laredo Ridge projects, which were acquired by NRG on April 1, 2014 and sold to the Company on January 1, 2015, as well as increased maintenance and operations costs for the RE Kansas South, TA High Desert, Alpine and Borrego facilities, which reached commercial operations in the first half of 2013	14	
 	
 	$	95	

5

Depreciation and Amortization
Depreciation and amortization increased by $105 million during the year ended December 31, 2014, compared to 2013, due to:

(In millions)	 	
Additional depreciation for Marsh Landing and El Segundo, which reached commercial operations in 2013, as well as due to Walnut Creek, which was acquired on April 1, 2014 by NRG and sold to the Company on January 2, 2015	$	62	
 	
Increase due to acquisition of Alta Wind Portfolio in August 2014	23	
 	
Additional depreciation due to the Tapestry and Laredo Ridge projects, which were acquired by NRG on April 1, 2014 and sold to the Company on January 2, 2015 as well as due to solar facilities that began operating in 2013 and the acquisition of Energy Systems in December 2013	20	
 	
 	$	105	
 	
Equity in Earnings of Unconsolidated Affiliates
Equity in earnings of unconsolidated affiliates increased by $5 million during the year ended December 31, 2014, compared to 2013, due primarily to an increase in income for CVSR as it reached commercial operations in late 2013.
Interest Expense     
Interest expense increased by $134 million during the year ended December 31, 2014, compared to the same period in 2013 due to:

(In millions)	 	
Interest expense on the project-level debt assumed in the Alta Wind Portfolio acquisition in August 2014	$	45	
 	
Issuance of Senior Notes in August 2014, Convertible Notes in March 2014 and to a lesser extent increased interest expense on the Company's revolving credit facility	30	
 	
Increase in interest expense in the Renewable segment primarily related to the Alpine interest rate swap	21	
 	
Increase due to the acquisition of the EME-NYLD-Eligible Assets by NRG on April 1, 2014 and sold to the Company on January 2, 2015	20	
 	
Increase in interest expense for the El Segundo and Marsh Landing projects which reached commercial operations in 2013	18	
 	
 	$	134	
 	
Income Tax Expense
For the year ended December 31, 2014, the Company recorded income tax expense of $4 million on pretax income of $116 million. For the same period in 2013, the Company recorded income tax expense of $8 million on pretax income of $140 million. For the year ended December 31, 2014, the overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its 55.3% interest in NRG Yield LLC and production tax credits generated from certain Alta Wind Portfolio facilities. For the same period in 2013, the Company's overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its 65.5% interest in NRG Yield LLC.
Income Attributable to NRG
Income attributable to NRG increased by $6 million for the year ended December 31, 2014, compared to the same period in 2013 due to the Company being public for the full year in 2014 compared to a shorter period in 2013, partially offset by a decrease in NRG's interest in the Company from 65.5% to 55.3% as a result of the equity offering on July 29, 2014.

6

Consolidated Results of Operations
2013 compared to 2012 
The following table provides selected financial information:

 	Year ended December 31,	
(In millions, except otherwise noted)	2013	 	2012	 	Change %	
Operating Revenues	 	 	 	 	 	
Total operating revenues	$	379	
 	 	$	175	
 	 	117	
 	
Operating Costs and Expenses	 	 	 	 	 	
Cost of operations	144	
 	 	114	
 	 	26	
 	
Depreciation and amortization	61	
 	 	25	
 	 	144	
 	
General and administrative — affiliate	7	
 	 	7	
 	 	—	
 	
Total operating costs and expenses	212	
 	 	146	
 	 	45	
 	
Operating Income	167	
 	 	29	
 	 	476	
 	
Other Income (Expense)	 	 	 	 	 	
Equity in earnings of unconsolidated affiliates	22	
 	 	19	
 	 	16	
 	
Other income, net	3	
 	 	2	
 	 	50	
 	
Interest expense	(52	)	 	(28	)	 	86	
 	
Total other expense	(27	)	 	(7	)	 	286	
 	
Income Before Income Taxes	140	
 	 	22	
 	 	N/M	
 	
Income tax expense	8	
 	 	10	
 	 	(20	)	
Net Income	132	
 	 	12	
 	 	N/M	
 	
Less: Pre-acquisition net income (loss) of Acquired ROFO Assets	23	
 	 	(1	)	 	

Net Income Excluding Pre-acquisition Net Income (Loss) of Acquired ROFO Assets	109	
 	 	$	13	

 	
Less: Predecessor income prior to initial public offering on July 22, 2013	54	
 	 	 	 	 	
Less: Net income attributable to NRG	42	
 	 	 	 	 	
Net Income Attributable to NRG Yield, Inc.	$	13	

 	
 	 	 	 	 	 	
 	Year ended December 31,	
Business metrics:	2013 (a)	 	2012 (a)	
Renewable MWh sold (in thousands)	854	
 	 	422	
 	
Thermal MWt sold (in thousands)	1,679	
 	 	1,517	
 	
(a) Volumes sold do not include MWh of 139 thousand and 88 thousand for thermal generation for the years ended December 31, 2013 and 2012, respectively.
N/M - Not meaningful.

7

Management’s discussion of the results of operations for the year ended December 31, 2013, and 2012
Operating Revenues    

 	Conventional	 	Renewables	 	Thermal	 	Total	
 (In millions)	 	 	 	
Year ended December 31, 2013	$	138	
 	 	$	89	
 	 	$	152	
 	 	$	379	
 	
Year ended December 31, 2012	—	
 	 	33	
 	 	142	
 	 	175	
 	
Operating revenuesincreased by $204 million during the year ended December 31, 2013, compared to 2012, due to:

(In millions)	 	
Increase in Conventional revenues as Marsh Landing and El Segundo reached commercial operations in 2013	$	138	
 	
Increase in Renewables revenue as TA High Desert, RE Kansas South, Alpine, Avra Valley, and Borrego reached commercial operations in late 2012 and early 2013	56	
 	
Increase in Thermal revenue due to repowering of Dover facilities in 2013 as well as a full year of operation of Princeton hospital	10	
 	
 	$	204	
 	
Cost of Operations

 	Conventional	 	Renewables	 	Thermal	 	Total	
 (In millions)	 	 	 	
Year ended December 31, 2013	$	23	
 	 	$	11	
 	 	$	110	
 	 	$	144	
 	
Year ended December 31, 2012	2	
 	 	9	
 	 	103	
 	 	114	
 	
Cost of operations increased by $30 million during the year ended December 31, 2013, compared to the same period in 2012, due to:

(In millions)	 	
Increase in Conventional costs as Marsh Landing and El Segundo reached commercial operations in 2013	$	21	
 	
Increase in Thermal costs due to repowering of Dover facilities in 2013 as well as a full year of operation of Princeton hospital	7	
 	
Increase in Renewables costs as TA High Desert, RE Kansas South, Alpine, Avra Valley, and Borrego reached commercial operations in late 2012 and early 2013	2	
 	
 	$	30	
 	
Depreciation and Amortization
Depreciation and amortization increased by $36 million during the year ended December 31, 2013, compared to the same period in 2012, due primarily to $20 million of additional depreciation associated with El Segundo and Marsh Landing which reached commercial operations in 2013 and $16 million for solar projects that reached commercial operations in late 2012 and early 2013.
Equity in Earnings of Unconsolidated Affiliates
Equity in earnings of unconsolidated affiliates increased by $3 million during the year ended December 31, 2013, compared to the same period in 2012, due primarily to CVSR reaching commercial operations in 2013.
Interest Expense     
Interest expense increased by $24 million during the year ended December 31, 2013, compared to the same period in 2012, due primarily to $25 million of interest expense related to Marsh Landing and El Segundo reaching commercial operations in 2013, which resulted in higher borrowings and less capitalized interest during 2013.

8

Income Tax Expense
For the year ended December 31, 2013, the Company recorded income tax expense of $8 million on pretax income of $140 million. For the same period in 2012, the Company recorded income tax expense of $10 million on pretax income of $22 million. For the year ended December 31, 2013, the Company's overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its 65.5% interest in NRG Yield LLC. For the year ended December 31, 2012, the Company's overall effective tax rate was different than the statutory rate of 35% primarily due to the impact of state and local income taxes.
Income Attributable to NRG
Income attributable to NRG of $42 million represents NRG's 65.5% interest in NRG Yield LLC's net income during the period from July 22, 2013 through December 31, 2013.

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, and to service debt. Historically, the Company's predecessor operations were financed as part of NRG's integrated operations and largely relied on internally generated cash flows as well as corporate and/or project-level borrowings to satisfy its capital expenditure requirements.  As a normal part of the Company's business, depending on market conditions, the Company will from time to time consider opportunities to repay, redeem, repurchase or refinance its indebtedness. Changes in the Company's operating plans, lower than anticipated sales, increased expenses, acquisitions or other events may cause the Company to seek additional debt or equity financing in future periods. There can be no guarantee that financing will be available on acceptable terms or at all. Debt financing, if available, could impose additional cash payment obligations and additional covenants and operating restrictions.
Liquidity Position
As of December 31, 2014, and December 31, 2013, the Company's liquidity was approximately $863 million and $186 million, respectively, comprised of cash, restricted cash, and availability under the Company's revolving credit facility. The increase primarily relates to the available line of credit under the revolving credit facility. The Company's various financing arrangements are described in Item 15  —  Note 9,  Long-term Debt.   On January 2, 2015, the Company borrowed $210 million under its revolving credit facility to fund the acquisition of Walnut Creek, Laredo Ridge and the Tapestry projects. On February 2, 2015 the Company made an optional repayment of $15 million of principal.
Management believes that the Company's liquidity position, cash flows from operations and availability under its revolving credit facility will be adequate to meet the Company's financial commitments, debt service obligations, finance growth, operating and maintenance capital expenditures, and to fund dividends to holders of the Company's Class A common stock and Class C common stock. Management continues to regularly monitor the Company's ability to finance the needs of its operating, financing and investing activity within the dictates of prudent balance sheet management.
Credit Ratings
Credit rating agencies rate a firm's public debt securities. These ratings are utilized by the debt markets in evaluating a firm's credit risk. Ratings influence the price paid to issue new debt securities by indicating to the market the Company's ability to pay principal, interest and preferred dividends. Rating agencies evaluate a firm's industry, cash flow, leverage, liquidity, and hedge profile, among other factors, in their credit analysis of a firm's credit risk.
The following table summarizes the credit ratings for the Company and its Senior Notes as of December 31, 2014:

 	S&P	 	Moody's	
NRG Yield, Inc. 	BB+	 	Ba1	
5.375% Senior Notes, due 2024	BB+	 	Ba1	

9

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 securities as appropriate given market conditions. As described in Item 15  —  Note 9,  Long-term Debt , the Company's financing arrangements consist of the revolving credit facility, the Convertible Notes, the Senior Notes and project-level financings for its various assets.
In connection with the initial public offering of the Company's Class A common stock, as further described in Item 15 —  Note 1,  Nature of Business , NRG Yield LLC and its direct wholly owned subsidiary, NRG Yield Operating LLC entered into a senior secured revolving credit facility, which provided a revolving line of credit of $60 million.  On April 25, 2014, the Company amended its revolving credit facility to increase the available line of credit to $450 million and extend its maturity to April 2019.   The revolving credit facility can be used for cash or for the issuance of letters of credit.
As described in Item 15 — Note 9, Long-term Debt, during the first quarter of 2014, the Company issued $345 million of Convertible Notes. The Convertible Notes are convertible, under certain circumstances, into the Company’s Class A common stock, cash or a combination thereof at an initial conversion price of $46.55 per share of Class A common stock, which is equivalent to an initial conversion rate of approximately 21.4822 shares of Class A common stock per $1,000 principal amount of Convertible Notes. The proceeds from the issuance were used primarily to fund the purchase of the Acquired ROFO Assets. In addition, on August 5, 2014, NRG Yield Operating LLC issued $500 million of Senior Notes, and used the proceeds to fund the acquisition of the Alta Wind Portfolio. The Senior Notes bear interest at 5.375% and mature in 2024.
On July 29, 2014, the Company issued 12,075,000 shares of Class A common stock for net proceeds, after underwriting discount and expenses, of $630 million. The proceeds were primarily used to fund the acquisition of the Alta Wind Portfolio and the excess of the proceeds over the amount utilized is available for general corporate purposes, including future acquisitions.
On May 5, 2015, the Company's stockholders voted and approved amendments to the Company's certificate of incorporation that would adjust the Company’s capital structure by creating two new classes of capital stock, Class C common stock and Class D common stock and distribute shares of the proposed Class C and Class D common stock to holders of the Company's outstanding Class A and Class B common stock, respectively, through a stock split. The recapitalization became effective on May 14, 2015.
The Class C common stock and Class D common stock have the same rights and privileges and rank equally, share ratably and are identical in all respects to the shares of Class A common stock and Class B common stock, respectively, as to all matters, except that each share of Class C common stock and Class D common stock is entitled to 1/100th of a vote on all stockholder matters. The par value per share of the Company’s Class A common stock and Class B common stock remains unchanged at $0.01 per share after the effect of the stock split described above. Accordingly, the stock split is accounted for as a stock dividend. The Company recorded a transfer between retained earnings and common stock equal to the par value of each share of Class C common stock and Class D common stock that is issued. The Company also gave retroactive effect to prior period share and per share amounts in the consolidated financial statements for the effect of the stock dividend, such that all periods are comparable.

In addition, subject to the approval of the proposed amendments described above, NRG has agreed to amend the ROFO Agreement to make additional assets available to the Company should NRG choose to sell them, including (i) two natural gas facilities totaling 895 MW of net capacity that are expected to reach COD in 2017 and 2020, (ii) an equity interest in a wind portfolio that includes wind facilities totaling approximately 934 MW of net capacity, and (iii) up to $250 million of equity interests in one or more residential or distributed solar generation portfolios developed by affiliates of NRG.

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 9 ,  Long-term Debt ; (ii) capital expenditures; and (iii) cash dividends to investors.

10

Debt Service Obligations
Principal payments on debt as of December 31, 2014, are due in the following periods:

Description	2015	 	2016	 	2017	 	2018	 	2019	 	There-after	 	Total	
 	(In millions)	
NRG Yield Inc. Convertible Notes, due 2019	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	345	
 	 	$	—	
 	 	$	345	
 	
NRG Yield Operating LLC Senior Notes, due 2024	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	500	
 	 	500	
 	
Project-level debt:	 	 	 	 	 	 	 	 	 	 	 	 	 	
Alta Wind I, lease financing arrangement, due 2034	10	
 	 	10	
 	 	10	
 	 	11	
 	 	12	
 	 	208	
 	 	261	
 	
Alta Wind II, lease financing arrangement, due 2034	7	
 	 	7	
 	 	8	
 	 	8	
 	 	8	
 	 	167	
 	 	205	
 	
Alta Wind III, lease financing arrangement, due 2034	7	
 	 	7	
 	 	8	
 	 	8	
 	 	8	
 	 	174	
 	 	212	
 	
Alta Wind IV, lease financing arrangement, due 2034	4	
 	 	5	
 	 	5	
 	 	5	
 	 	6	
 	 	113	
 	 	138	
 	
Alta Wind V, lease financing arrangement, due 2035	7	
 	 	7	
 	 	8	
 	 	8	
 	 	8	
 	 	182	
 	 	220	
 	
Alta Wind X, due 2021	—	
 	 	13	
 	 	13	
 	 	13	
 	 	13	
 	 	248	
 	 	300	
 	
Alta Wind XI, due 2021	—	
 	 	8	
 	 	9	
 	 	8	
 	 	9	
 	 	157	
 	 	191	
 	
Alta Realty Investments, due 2031	1	
 	 	1	
 	 	1	
 	 	2	
 	 	2	
 	 	27	
 	 	34	
 	
Alta Wind Asset Management, due 2031	1	
 	 	1	
 	 	1	
 	 	1	
 	 	1	
 	 	15	
 	 	20	
 	
NRG West Holdings LLC, due 2023	36	
 	 	41	
 	 	41	
 	 	47	
 	 	49	
 	 	292	
 	 	506	
 	
NRG Marsh Landing LLC, due 2017 and 2023	46	
 	 	48	
 	 	52	
 	 	55	
 	 	57	
 	 	206	
 	 	464	
 	
Walnut Creek Energy, due 2023	39	
 	 	41	
 	 	43	
 	 	45	
 	 	47	
 	 	175	
 	 	390	
 	
Tapestry Wind LLC, due 2021	11	
 	 	9	
 	 	10	
 	 	11	
 	 	11	
 	 	139	
 	 	191	
 	
NRG Solar Alpine LLC, due 2014 and 2022	9	
 	 	9	
 	 	9	
 	 	8	
 	 	8	
 	 	120	
 	 	163	
 	
NRG Energy Center Minneapolis LLC, due 2017 and 2025	12	
 	 	13	
 	 	13	
 	 	8	
 	 	11	
 	 	64	
 	 	121	
 	
Laredo Ridge LLC, due 2026	4	
 	 	5	
 	 	5	
 	 	5	
 	 	5	
 	 	84	
 	 	108	
 	
NRG Solar Borrego LLC, due 2024 and 2038	3	
 	 	3	
 	 	3	
 	 	2	
 	 	2	
 	 	62	
 	 	75	
 	
South Trent Wind LLC, due 2020	4	
 	 	4	
 	 	4	
 	 	4	
 	 	4	
 	 	45	
 	 	65	
 	
NRG Solar Avra Valley LLC, due 2031	3	
 	 	3	
 	 	3	
 	 	3	
 	 	4	
 	 	47	
 	 	63	
 	
TA High Desert LLC, due 2023 and 2033	3	
 	 	3	
 	 	3	
 	 	3	
 	 	3	
 	 	40	
 	 	55	
 	
WCEP Holdings LLC, due 2023	1	
 	 	1	
 	 	1	
 	 	2	
 	 	4	
 	 	39	
 	 	48	
 	
NRG Roadrunner LLC, due 2031	2	
 	 	2	
 	 	3	
 	 	3	
 	 	3	
 	 	29	
 	 	42	
 	
NRG Solar Kansas South LLC, due 2031	2	
 	 	2	
 	 	2	
 	 	2	
 	 	2	
 	 	25	
 	 	35	
 	
NRG Solar Blythe LLC, due 2028	1	
 	 	1	
 	 	2	
 	 	1	
 	 	2	
 	 	15	
 	 	22	
 	
PFMG and related subsidiaries financing agreement, due 2030	1	
 	 	2	
 	 	2	
 	 	1	
 	 	1	
 	 	24	
 	 	31	
 	
NRG Energy Center Princeton LLC, due 2017	1	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	1	
 	
Total debt	$	215	
 	 	$	246	
 	 	$	259	
 	
 	$	264	
 	
 	$	625	
 	
 	$	3,197	
 	
 	$	4,806	

Capital Expenditures
The Company's capital spending program is focused on growth capital expenditures, or construction of new assets and completing the construction of assets where construction is in process, and maintenance capital expenditures, or costs to maintain the assets currently operating such as costs to replace or refurbish assets during routine maintenance. The Company develops annual capital spending plans based on projected requirements for maintenance capital and completion of facilities under construction. For the years ended  December 31, 2014 , 2013, and 2012, the Company used approximately $33 million, $353 million, and $564 million, respectively, to fund capital expenditures, including maintenance  capital  expenditures  of $8 million, $8 million and $5 million, respectively. Growth capital expenditures primarily related to the construction of the Company’s solar generating assets, Marsh Landing and El Segundo.
In January 2015, El Segundo experienced a steam turbine water intrusion resulting in a forced outage on Units 5 and 6.  The Company has undertaken a root cause analysis and is reviewing the financial impact of repair costs and capacity revenue loss that are not otherwise covered by warranty or available insurance coverage.  The units are expected to return to service early in the second quarter of 2015.

11

Acquisitions
The Company intends to acquire generation assets developed and constructed by NRG in the future, as well as generation and thermal infrastructure assets from third parties where the Company believes its knowledge of the market, operating expertise and access to capital provides a competitive advantage, and to utilize such acquisitions as a means to grow its cash available for distribution. 
On June 30, 2014, NRG Yield Operating LLC acquired the El Segundo, TA High Desert, and RE Kansas South projects for a total cash consideration of $357 million, which represents a base purchase price of $349 million and $8 million of working capital adjustments. In addition, the acquisition included the assumption of $612 million in project level debt. The assets and liabilities transferred to the Company relate to interests under common control by NRG and accordingly, were recorded at historical cost in accordance with ASC 805-50,  Business Combinations - Related Issues .
OnAugust 12, 2014, the Company acquired 100% of the membership interests of Alta Wind Asset Management Holdings, LLC, Alta Wind Company, LLC, Alta Wind X Holding Company, LLC and Alta Wind XI Holding Company, LLC for $923 million, which included a base purchase price of $870 million, as well as a payment for working capital of $53 million, plus the assumption of $1.6 billion of non-recourse project-level debt. In order to fund the purchase price, the Company completed an equity offering of 12,075,000 shares of its Class A common stock at an offering price of $54.00 per share on July 29, 2014, which resulted in net proceeds of $630 million and on August 5, 2014, NRG Yield Operating LLC issued $500 million of Senior Notes which bear interest at a rate of 5.375% and mature in August 2024.
On January 2, 2015, NRG Yield Operating LLC acquired the following projects from NRG: (i) Laredo Ridge, a 80 MW wind facility located in Petersburg, Nebraska, (ii) the Tapestry projects, which include Buffalo Bear, a 19 MW wind facility in Oklahoma, Taloga, a 130 MW wind facility in Oklahoma, and Pinnacle, a 55 MW wind facility in West Virginia, and (iii)  Walnut Creek, a 485 MW natural gas facility located in City of Industry, California, for total cash consideration of $489 million including adjustments of $9 million for working capital, plus assumed project level debt of $737 million. The Company funded the acquisition with cash on hand and approximately  $210 million  borrowed under the Company's revolving credit facility.
On February 26, 2015, NRG Yield Operating LLC entered into a definitive agreement with Invenergy Wind Global LLC to acquire a majority interest in Spring Canyon II, a 34 MW wind facility, and Spring Canyon III, a 29 MW wind facility, each located in Logan County, Colorado. The purchase price will be funded with cash on hand. The acquisition is subject to customary closing conditions, including the receipt of regulatory and third party approvals. The Company expects the acquisition to close during the second quarter of 2015. Power generated by Spring Canyon II and Spring Canyon III is sold to Platte River Power Authority under long-term PPAs with approximately 25 years of remaining contract life.

Cash Dividends to Investors
The Company intends to use the amount of cash that it receives from its distributions from NRG Yield LLC to pay quarterly dividends to the holders of its Class A and Class C common stock. NRG Yield LLC intends to distribute to its unit holders in the form of a quarterly distribution all of the cash available for distribution that is generated each quarter less reserves for the prudent conduct of the business, including among others, maintenance capital expenditures to maintain the operating capacity of the assets. Cash available for distribution is defined as earnings before income taxes, depreciation and amortization, excluding contract amortization, cash interest paid, income taxes paid, maintenance capital expenditures, investments in unconsolidated affiliates, growth capital expenditures, net of capital and debt funding, and principal amortization of indebtedness, and including cash distributions from unconsolidated affiliates.  The common stock dividend is subject to available capital, market conditions, and compliance with associated laws and regulations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.
The following table lists the dividends paid on the Company's Class A common stock during the year ended December 31, 2014:

 	Fourth Quarter 2014	 	Third Quarter 2014	 	Second Quarter 2014	 	First Quarter 2014	
Dividends per share	$	0.375	
 	 	$	0.365	
 	 	$	0.35	
 	 	$	0.33	
 	
On February 17, 2015, the Company declared a quarterly dividend on its Class A common stock of $0.39 per share payable on March 16, 2015, to stockholders of record as of March 2, 2015.

12

Cash Flow Discussion
Year Ended December 31, 2014 Compared to Year Ended December 31, 2013 
The following table reflects the changes in cash flows for the year ended December 31, 2014, compared to 2013:

Year ended December 31,	2014	 	2013	 	Change	
(In millions)	 	
Net cash provided by operating activities	$	293	
 	 	$	120	
 	 	$	173	
 	
Net cash used in investing activities	(1,057	)	 	(515	)	 	(542	)	
Net cash provided by financing activities	1,111	
 	 	432	
 	 	679	
 	
Net Cash Provided By Operating Activities

Changes to net cash provided by operating activities were driven by:	(In millions)	
Increase in operating income due to Walnut Creek, El Segundo, Marsh Landing and most of the Renewable projects being placed in service in late 2012 or 2013 and the acquired EME-NYLD-Eligible Assets, adjusted for non-cash charges	$	126	
 	
Higher net distributions from unconsolidated affiliates for the period ending December 31, 2014 compared to the same period in 2013	3	
 	
Decreased working capital requirements due to assets placed in service in late 2012 and 2013	44	
 	
 	$	173	
 	
Net Cash Used In Investing Activities

Changes to net cash used in investing activities were driven by:	(In millions)	
Increase in cash paid for Alta Wind Portfolio in 2014 compared to cash paid for Energy Systems in 2013	$	(781	)	
Payment to NRG for Acquired ROFO Assets	(336	)	
Decrease in capital expenditures for El Segundo, Marsh Landing and some of the Renewable projects, as the assets were placed in service in late 2012 or 2013	320	
 	
Decrease in restricted cash, primarily for Marsh Landing, Borrego, Alta Wind Portfolio, Tapestry, El Segundo, Alpine and High Desert	93	
 	
Increase in notes receivable, including affiliates	(2	)	
Increase in proceeds from renewable grants in 2014 compared to 2013	112	
 	
Decrease in investments in unconsolidated affiliates in 2014 compared to 2013 and other	52	
 	
 	$	(542	)	
Net Cash Provided By Financing Activities

Changes in net cash provided by financing activities were driven by:	(In millions)	
Decrease in dividends and returns of capital to NRG, net of change in cash contributions from NRG	$	452	
 	
Increase due to the $630 million equity offering of Class A common stock on July 29, 2014, compared to the prior year initial public offering of $468 million	162	
 	
Increase in cash received from issuance of Senior Notes and other long term debt, partially offset by higher principal payments in 2014 compared to 2013	182	
 	
Increase in dividends paid in 2014 compared to 2013	(86	)	
Increase in cash paid for deferred financing costs	(31	)	
 	$	679	

13

Year Ended December 31, 2013 Compared to Year Ended December 31, 2012 
The following table reflects the changes in cash flows for the year ended December 31, 2013, compared to 2012:

Year ended December 31,	2013	 	2012	 	Change	
(In millions)	 	
Net cash provided by operating activities	$	120	
 	 	$	56	
 	 	$	64	
 	
Net cash used in investing activities	(515	)	 	(594	)	 	79	
 	
Net cash provided by financing activities	432	
 	 	536	
 	 	(104	)	
Net Cash Provided By Operating Activities

Changes to net cash provided by operating activities were driven by:	(In millions)	
Increase in operating income due to Borrego, Avra Valley, Alpine, RE Kansas South, High Desert, El Segundo and Marsh Landing being placed in service in late 2012 or 2013 adjusted for non-cash charges	$	136	
 	
Higher net distributions from unconsolidated affiliates for the period ending December 31, 2013 compared to the same period in 2012	(8	)	
Increased working capital requirements due to assets placed in service in late 2012 and 2013	(64	)	
 	$	64	
 	
Net Cash Used In Investing Activities

Changes to net cash used in investing activities were driven by:	(In millions)	
Acquisition of Energy Systems in December 2013	$	(120	)	
Decrease in capital expenditures for El Segundo, Marsh Landing, Borrego, Avra Valley and Alpine as the assets were placed in service in late 2012 or 2013	211	
 	
Increase in restricted cash, primarily for Marsh Landing and El Segundo	(31	)	
Decrease in notes receivable, including affiliates	27	
 	
Decrease in proceeds from renewable grants	(3	)	
Increase in investments in unconsolidated affiliates	(7	)	
Other	2	
 	
 	$	79	
 	
Net Cash Provided By Financing Activities

Changes in net cash provided by financing activities were driven by:	(In millions)	
Increase in dividends and returns of capital to NRG, net of change in cash contributions from NRG	$	(819	)	
Proceeds from the issuance of Class A common stock	468	
 	
Dividends to Class A and Class B common shareholders in 2013	(15	)	
Net increase in cash received from proceeds for issuance of long-term debt, net of payments	255	
 	
Decrease in cash paid for deferred financing costs	7	
 	
 	$	(104	)	
NOLs, Deferred Tax Assets and Uncertain Tax Position Implications, under ASC 740
As of December 31, 2014, the Company has a cumulative federal NOL carry forward balance of $219 million for financial statement purposes, which will begin expiring in 2033, and does not anticipate any federal income tax payments for 2015. As a result of the Company's tax position, and based on current forecasts, the Company does not anticipate significant income tax payments for state and local jurisdictions in 2015.
The Company has no uncertain tax benefits.

14

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, 2014, 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. One of these investments, GenConn Energy LLC, is a variable interest entity 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 $567 million as of December 31, 2014. 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 .
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 9,  Long-term Debt  and Item 15 - Note 15,  Commitments and Contingencies , to the Company's audited financial statements for additional discussion.

 	By Remaining Maturity at December 31,	
 	2014	 	 	
Contractual Cash Obligations	Under
1 Year	 	1-3 Years	 	3-5 Years	 	Over
5 Years	 	Total	 	2013	
 	(In millions)	
Long-term debt (including estimated interest)	$	457	
 	 	$	980	
 	 	$	1,313	
 	 	$	4,334	
 	 	$	7,084	
 	 	$	2,225	
 	
Operating leases	12	
 	 	18	
 	 	14	
 	 	133	
 	 	177	
 	 	25	
 	
Fuel purchase and transportation obligations	15	
 	 	7	
 	 	5	
 	 	26	
 	 	53	
 	 	55	
 	
Other liabilities	9	
 	 	18	
 	 	17	
 	 	74	
 	 	118	
 	 	78	
 	
Total	$	493	
 	 	$	1,023	
 	 	$	1,349	
 	 	$	4,567	
 	 	$	7,432	
 	 	$	2,383	
 	
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 and fixed rate debt, the Company enters into interest rate swap agreements.
The tables below disclose the activities that include 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, 2014 , based on their level within the fair value hierarchy defined in ASC 820; and indicate the maturities of contracts at  December 31, 2014 . 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 .

Derivative Activity Gains/(Losses)	(In millions)	
Fair value of contracts as of December 31, 2013	$	(26	)	
Contracts realized or otherwise settled during the period	31	
 	
Contracts acquired during the period	(21	)	
Changes in fair value	(99	)	
Fair Value of Contracts as of December 31, 2014	$	(115	)	

15

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Fair Value of Contracts as of December 31, 2014	
 	Maturity	 	 	
Fair value hierarchy Gains/(Losses)	1 Year or Less	 	Greater Than 1 Year to 3 Years	 	Greater Than 3 Years to 5 Years	 	Greater Than 5 Years	 	Total Fair
Value	
 	(In millions)	
Level 2	$	(47	)	 	$	(45	)	 	$	(11	)	 	$	(12	)	 	$	(115	)	
The Company has elected to disclose derivative assets and liabilities on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As discussed below in  Quantitative and Qualitative Disclosures about Market Risk -Commodity Price Risk,  NRG, on behalf of the  Company, measures the sensitivity of the portfolio to potential changes in market prices using VaR, a statistical model which attempts to predict risk of loss based on market price and volatility. NRG's risk management policy places a limit on one-day holding period VaR, which limits the net open position.

Critical Accounting Policies and Estimates
The Company's discussion and analysis of the financial condition and results of operations are based upon the consolidated financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of these financial statements and related disclosures in compliance with U.S. GAAP requires the application of appropriate technical accounting rules and guidance as well as the use of estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities. The application of these policies necessarily involves judgments regarding future events, including the likelihood of success of particular projects, legal and regulatory challenges, and the fair value of certain assets and liabilities. These judgments, in and of themselves, could materially affect the financial statements and disclosures based on varying assumptions, which may be appropriate to use. In addition, the financial and operating environment may also have a significant effect, not only on the operation of the business, but on the results reported through the application of accounting measures used in preparing the financial statements and related disclosures, even if the nature of the accounting policies has not changed.
On an ongoing basis, the Company evaluates these estimates, utilizing historic experience, consultation with experts and other methods the Company considers reasonable. In any event, actual results may differ substantially from the Company's estimates. Any effects on the Company's business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the information that gives rise to the revision becomes known.
The Company's significant accounting policies are summarized in Item 15 — Note 2, Summary of Significant Accounting Policies . The Company identifies its most critical accounting policies as those that are the most pervasive and important to the portrayal of the Company's financial position and results of operations, and that require the most difficult, subjective and/or complex judgments by management regarding estimates about matters that are inherently uncertain. The Company's critical accounting policies include income taxes and valuation allowance for deferred tax assets, impairment of long lived assets and other intangible assets, and acquisition accounting.

16

 	
 	 	
Accounting Policy	Judgments/Uncertainties Affecting Application	
 	 	
Income Taxes and Valuation Allowance for Deferred Tax Assets	Ability to withstand legal challenges of tax authority decisions or appeals	
 	Anticipated future decisions of tax authorities	
 	Application of tax statutes and regulations to transactions	
 	Ability to utilize tax benefits through carry backs to prior periods and carry forwards to future periods	
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	

Income Taxes and Valuation Allowance for Deferred Tax Assets
In assessing the recoverability of deferred tax assets, the Company considers whether it is more likely than not that some portion or all of the deferred tax assets will be realized. The ultimate realization of deferred tax assets is primarily dependent upon earnings in various jurisdictions.
The Company's operating companies, as former subsidiaries of NRG, continue to be under audit for multiple years by taxing authorities in other jurisdictions. Considerable judgment is required to determine the tax treatment of a particular item that involves interpretations of complex tax laws. The project-level entities, as former subsidiaries of NRG, are subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state and local jurisdictions. NRG is no longer subject to U.S. federal income tax examinations for years prior to 2010. With few exceptions, state and local income tax examinations are no longer open for years before 2009.
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 by factoring in the probability weighting of different courses of action available to us. Generally, fair value will be determined using valuation techniques such as the present value of expected future cash flows. 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.

17

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 an "other than a 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.
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.
Recent Accounting Developments
See Item 15 — Note 2, Summary of Significant Accounting Policies, to the audited financial statements for a discussion of recent accounting developments.

18

Exhibit 99.3

Item 15 — Exhibits, Financial Statement Schedules
(a)(1) Consolidated Financial Statements
The following consolidated financial statements of NRG Yield, Inc. and related notes thereto, together with the report thereon of KPMG LLP, are included herein:
Consolidated Statements of Operations — Years ended December 31, 2014, 2013 and 2012 
Consolidated Statements of Comprehensive Income (Loss) — Years ended December 31, 2014, 2013 and 2012 
Consolidated Balance Sheets — December 31, 2014 and 2013
Consolidated Statements of Cash Flows — Years ended December 31, 2014, 2013 and 2012 
Consolidated Statement of Stockholders' Equity — Years ended December 31, 2014, 2013 and 2012 
Notes to Consolidated Financial Statements
(a)(2) Financial Statement Schedule
The following schedules of NRG Yield, Inc. are filed as part of Item 15 of this report and should be read in conjunction with the Consolidated Financial Statements.
NRG Yield, Inc. Financial Statements for the year ended December 31, 2014 and 2013 are included in NRG Yield, Inc.'s Annual Report on Form 10-K pursuant to the requirements of Rule 5-04(c) of Regulation S-X

1

                                                

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholders
NRG Yield, Inc.:
We have audited the accompanying consolidated balance sheets of NRG Yield, Inc. and subsidiaries as of December 31, 2014 and 2013, and the related consolidated statements of operations, comprehensive income (loss), stockholders’ equity, and cash flows for each of the years in the three‑year period ended December 31, 2014. In connection with our audits of the consolidated financial statements, we also have audited financial statement schedule “Schedule I. Condensed Financial Information of Registrant.” These consolidated financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements and financial statement schedules based on our audits. We did not audit the December 31, 2012 consolidated financial statements of GCE Holding, LLC (a 50% owned investee company). The Company’s investment in GCE Holding, LLC at December 31, 2012 was $125 million, and its equity in earnings of GCE Holding, LLC was $15 million for the year ended December 31, 2012. The consolidated financial statements of GCE Holding, LLC were audited by other auditors whose report has been furnished to us, and our opinion, insofar as it relates to the amounts included for GCE Holding, LLC, is based solely on the report of the other auditors.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, based on our audits and the report of the other auditors, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of NRG Yield, Inc. and subsidiaries as of December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the years in the three‑year period ended December 31, 2014, in conformity with U.S. generally accepted accounting principles. Also in our opinion, the related financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), NRG Yield, Inc.’s internal control over financial reporting as of December 31, 2014, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 27, 2015 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.
Our report dated February 27, 2015, on the effectiveness of internal control over financial reporting as of December 31, 2014, contains an explanatory paragraph that states that the scope of management’s assessment of their effectiveness of internal control over financial reporting included the Company’s consolidated operations except for the operations of Alta Wind Portfolio, which the Company acquired in August 2014. Alta Wind Portfolio represented 35% of the Company’s consolidated total assets and 7% of consolidated operating revenues as of and for the year ended December 31, 2014. Our audit of internal control over financial reporting of NRG Yield, Inc. also excluded an evaluation of the internal control over financial reporting of Alta Wind Portfolio.

/s/ KPMG LLP
Philadelphia, Pennsylvania
May 22, 2015

2

NRG YIELD, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS

 	Year ended December 31,	
(In millions, except per share amounts)	2014 (a)	 	2013 (a)	 	2012 (a)	
Operating Revenues	 	 	 	 	 	
Total operating revenues	$	689	
 	 	$	379	
 	 	$	175	
 	
Operating Costs and Expenses	 	 	 	 	 	
Cost of operations	239	
 	 	144	
 	 	114	
 	
Depreciation and amortization	166	
 	 	61	
 	 	25	
 	
General and administrative — affiliate	8	
 	 	7	
 	 	7	
 	
Acquisition-related transaction and integration costs	4	
 	 	—	
 	 	—	
 	
Total operating costs and expenses	417	
 	 	212	
 	 	146	
 	
Operating Income	272	
 	 	167	
 	 	29	
 	
Other Income (Expense)	 	 	 	 	 	
Equity in earnings of unconsolidated affiliates	27	
 	 	22	
 	 	19	
 	
Other income, net	3	
 	 	3	
 	 	2	
 	
Interest expense	(186	)	 	(52	)	 	(28	)	
Total other expense	(156	)	 	(27	)	 	(7	)	
Income Before Income Taxes	116	
 	 	140	
 	 	22	
 	
Income tax expense	4	
 	 	8	
 	 	10	
 	
Net Income	$	112	
 	 	$	132	
 	 	$	12	
 	
Less: Pre-acquisition net income of Drop Down Assets	48	
 	 	23	
 	 	 	
Net Income Excluding Pre-acquisition Net Income of Drop Down Assets	64	
 	 	109	

 	
Less: Predecessor income prior to initial public offering on July 22, 2013	—	
 	 	54	

 	
Less: Net income attributable to NRG (b)	48	
 	 	42	

 	
Net Income Attributable to NRG Yield, Inc.	$	16	
 	 	$	13	

 	
Earnings Per Share Attributable to NRG Yield, Inc. Class A and Class C Common Stockholders:	 	 	 	 	 	
Weighted average number of Class A common shares outstanding - basic and diluted	28	
 	 	23	
 	 	 	
Weighted average number of Class C common shares outstanding - basic and diluted	28	
 	 	23	
 	 	 	
Earnings per Weighted Average Class A Common Share - Basic and Diluted	$	0.30	
 	 	$	0.29	
 	 	 	
Earnings per Weighted Average Class C Common Share - Basic and Diluted	$	0.30	
 	 	$	0.29	
 	 	 	
Dividends Per Class A Common Share	$	1.42	
 	 	$	0.23	

 	

(a)Retrospectively adjusted as discussed in Note 1, Nature of Business.
(b)The calculation of income attributable to NRG excludes pre-acquisition net income of the Drop Down Assets.
See accompanying notes to consolidated financial statements.

3

NRG YIELD, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

 	Year ended December 31,	
 	2014 (a)	 	2013 (a)	 	2012 (a)	
 	(In millions)	
Net Income	$	112	
 	 	$	132	
 	 	$	12	
 	
Other Comprehensive (Loss) Income, net of tax	 	 	 	 	 	
Unrealized (loss) gain on derivatives, net of income tax benefit (expense) of $5, $(16), and $7	(52	)	 	48	
 	 	(20	)	
Other comprehensive (loss) income	(52	)	 	48	
 	 	(20	)	
Comprehensive Income (Loss)	60	
 	 	180	
 	 	$	(8	)	
Less: Predecessor comprehensive income prior to initial public offering on July 22, 2013	—	
 	 	73	
 	 	 	
Less: Pre-acquisition net income of Drop Down Assets	48	
 	 	23	
 	 	 	
Less: Comprehensive income attributable to NRG	5	
 	 	69	
 	 	 	
Comprehensive Income Attributed to NRG Yield Inc.	$	7	
 	 	$	15	

 	

(a)Retrospectively adjusted as discussed in Note 1, Nature of Business.
See accompanying notes to consolidated financial statements.

4

NRG YIELD, INC.
CONSOLIDATED BALANCE SHEETS

 	December 31, 2014 (a)	 	December 31, 2013 (a)	
ASSETS	(In millions)	
Current Assets	 	 	 	
Cash and cash equivalents	$	406	
 	 	$	59	
 	
Restricted cash	45	
 	 	67	
 	
Accounts receivable — trade	85	
 	 	51	
 	
Accounts receivable — affiliate	—	
 	 	5	
 	
Inventory	27	
 	 	15	
 	
Derivative instruments	—	
 	 	1	
 	
Notes receivable	6	
 	 	6	
 	
Renewable energy grant receivable	—	
 	 	147	
 	
Deferred income taxes	16	
 	 	—	
 	
Prepayments and other current assets	21	
 	 	27	
 	
Total current assets	606	
 	 	378	
 	
Property, plant and equipment	 	 	 	
In service	4,796	
 	 	2,459	
 	
Under construction	8	
 	 	6	
 	
Total property, plant and equipment	4,804	
 	 	2,465	
 	
Less accumulated depreciation	(338	)	 	(174	)	
Net property, plant and equipment	4,466	
 	 	2,291	
 	
Other Assets	 	 	 	
Equity investments in affiliates	227	
 	 	227	
 	
Notes receivable	15	
 	 	21	
 	
Notes receivable — affiliate	—	
 	 	2	
 	
 Intangible assets, net of accumulated amortization of $36 and $7	1,423	
 	 	103	
 	
Derivative instruments	2	
 	 	20	
 	
Deferred income taxes	118	
 	 	146	
 	
Other non-current assets	108	
 	 	50	
 	
Total other assets	1,893	
 	 	569	
 	
Total Assets	$	6,965	
 	 	$	3,238	

 	

(a)Retrospectively adjusted as discussed in Note 1, Nature of Business.
See accompanying notes to consolidated financial statements.

5

NRG YIELD, INC.
CONSOLIDATED BALANCE SHEETS (Continued)

 	December 31, 2014 (a)	 	December 31, 2013 (a)	
LIABILITIES AND STOCKHOLDERS’ EQUITY	(In millions, except share information)	
Current Liabilities	 	 	 	
Current portion of long-term debt	$	214	
 	 	$	214	
 	
Accounts payable	20	
 	 	42	
 	
Accounts payable — affiliate	46	
 	 	52	
 	
Derivative instruments	48	
 	 	31	
 	
Accrued expenses and other current liabilities	61	
 	 	30	
 	
Total current liabilities	389	
 	 	369	
 	
Other Liabilities	 	 	 	
Long-term debt	4,573	
 	 	1,569	
 	
Derivative instruments	69	
 	 	16	
 	
Other non-current liabilities	49	
 	 	32	
 	
Total non-current liabilities	4,691	
 	 	1,617	
 	
Total Liabilities	5,080	
 	 	1,986	
 	
Commitments and Contingencies	—	
 	 	—	
 	
Stockholders' Equity	 	 	 	
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued	—	
 	 	—	
 	
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 154,650,000 (Class A 34,586,250, Class B 42,738,750, Class C 34,586,250, Class D 42,738,750) and 130,500,540 (Class A 22,511,520, Class B 42,738,750, Class C 22,511,520, Class D 42,738,750) shares issued and outstanding at December 31, 2014 and 2013	—	
 	 	—	
 	
Additional paid-in capital	1,240	
 	 	621	
 	
Retained earnings	3	
 	 	8	
 	
Accumulated other comprehensive loss	(9	)	 	—	
 	
Noncontrolling interest	651	
 	 	623	
 	
Total Stockholders' Equity	1,885	
 	 	1,252	
 	
Total Liabilities and Stockholders' Equity	$	6,965	
 	 	$	3,238	

 	

(a)Retrospectively adjusted as discussed in Note 1, Nature of Business.
See accompanying notes to consolidated financial statements.

6

NRG YIELD, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS

 	Year ended December 31,	
 	2014 (a)	 	2013 (a)	 	2012 (a)	
 	(In millions)	
Cash Flows from Operating Activities	 	 	 	 	 	
Net income	$	112	
 	 	$	132	
 	 	$	12	
 	
Adjustments to reconcile net income to net cash provided by operating activities:	 	 	 	 	 	
Distributions and equity in earnings of unconsolidated affiliates	(3	)	 	(6	)	 	2	
 	
Depreciation and amortization	166	
 	 	61	
 	 	25	
 	
Amortization of financing costs and debt discount/premiums	10	
 	 	4	
 	 	—	
 	
Amortization of intangibles and out-of-market contracts	27	
 	 	1	
 	 	—	
 	
Changes in deferred income taxes	4	
 	 	8	
 	 	10	
 	
Changes in derivative instruments	(8	)	 	(21	)	 	2	
 	
Changes in other working capital	(15	)	 	(59	)	 	5	
 	
Net Cash Provided by Operating Activities	293	
 	 	120	
 	
 	56	
 	
Cash Flows from Investing Activities	 	 	 	 	 	
Acquisition of businesses, net of cash acquired	(901	)	 	(120	)	 	—	
 	
Payment to NRG for Drop Down assets, net of cash acquired	(336	)	 	—	
 	 	—	
 	
Capital expenditures	(33	)	 	(353	)	 	(564	)	
Decrease (increase) in restricted cash	50	
 	 	(43	)	 	(12	)	
Decrease (increase) in notes receivable, including affiliates	8	
 	 	10	
 	 	(17	)	
Proceeds from renewable energy grants	137	
 	 	25	
 	 	28	
 	
Investments in unconsolidated affiliates	7	
 	 	(34	)	 	(27	)	
Other	11	
 	 	—	
 	 	(2	)	
Net Cash Used in Investing Activities	(1,057	)	 	(515	)	
 	(594	)	
Cash Flows from Financing Activities	 	 	 	 	 	
Capital contributions from NRG	2	
 	 	171	
 	 	355	
 	
Distributions and return of capital to NRG	(86	)	 	(707	)	 	(72	)	
Proceeds from issuance of Class A common stock	630	
 	 	468	
 	 	—	
 	
Payment of dividends and distributions	(101	)	 	(15	)	 	—	
 	
Proceeds from issuance of long-term debt — external	975	
 	 	594	
 	 	308	
 	
Payment of debt issuance costs	(36	)	 	(5	)	 	(12	)	
Payments for long-term debt — external	(273	)	 	(72	)	 	(37	)	
Payments for long-term debt — affiliate	—	
 	 	(2	)	 	(6	)	
Net Cash Provided by Financing Activities	1,111	
 	 	432	
 	 	536	
 	
Net Increase (Decrease) in Cash and Cash Equivalents	347	
 	 	37	
 	 	(2	)	
Cash and Cash Equivalents at Beginning of Period	59	
 	 	22	
 	 	24	
 	
Cash and Cash Equivalents at End of Period	$	406	
 	 	$	59	
 	 	$	22	

Supplemental Disclosures	 	 	 	 	 	
Interest paid, net of amount capitalized	$	(174	)	 	$	(63	)	 	$	(17	)	
Non-cash investing and financing activities:	 	 	 	 	 	
Additions to fixed assets for accrued capital expenditures	—	
 	 	1	
 	 	121	
 	
Decrease to fixed assets for accrued grants	—	
 	 	(207	)	 	(1	)	
Decrease to fixed assets for deferred tax asset	—	
 	 	(12	)	 	—	
 	
Non-cash addition to additional paid-in capital for change in tax basis of property, plant and equipment for assets acquired from NRG	(14	)	 	153	
 	 	—	
 	
Non-cash capital contributions from NRG	16	
 	 	80	
 	 	166	
 	
Non-cash return of capital and dividends to NRG	—	
 	 	(76	)	 	—	

 	

(a)Retrospectively adjusted as discussed in Note 1, Nature of Business.
See accompanying notes to consolidated financial statements.

7

NRG YIELD, INC.
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY

 	Preferred Stock	 	Class A Common Stock	 	Class B Common Stock	 	Class C Common Stock	 	Class D Common Stock	 	Additional
Paid-In
Capital	 	Retained Earnings	 	Accumulated
Other
Comprehensive
Income (Loss)	 	Noncon-trolling
Interest	 	Members' Equity  (a)	 	Total
Members'/Stockholders'
Equity (a)	
 	(In millions)	
Balance as of December 31, 2011  (b)	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	387	
 	 	$	387	
 	
Members' equity - Acquired ROFO Assets	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	174	
 	 	174	
 	
Balances at December 31, 2011	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	561	
 	 	$	561	
 	
Net Income	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	$	12	
 	 	$	12	
 	
Unrealized gain on derivatives, net of tax	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(20	)	 	(20	)	
Capital contributions from NRG, cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	355	
 	 	355	
 	
Capital contributions from NRG, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	166	
 	 	166	
 	
Dividends and return of capital to NRG, cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(72	)	 	(72	)	
Balances at December 31, 2012	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	1,002	
 	 	$	1,002	
 	
Net Income	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	54	
 	 	54	
 	
Unrealized gain on derivatives, net of tax	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	38	
 	 	38	
 	
Capital contributions from NRG, cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	171	
 	 	171	
 	
Capital contributions from NRG, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	66	
 	 	66	
 	
Dividends and return of capital to NRG, cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(312	)	 	(312	)	
Dividends and return of capital to NRG, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(33	)	 	(33	)	
Balance as of July 22, 2013	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	986	
 	 	$	986	
 	
Net Income	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	13	
 	 	—	
 	 	65	
 	 	—	
 	 	78	
 	
Unrealized (loss) gain on derivatives, net	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(3	)	 	9	
 	 	—	
 	 	6	
 	
Capital contributions from NRG, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	14	
 	 	—	
 	 	14	
 	
Distributions and return of capital to NRG, cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(395	)	 	(395	)	
Transfer of predecessors' equity to noncontrolling interest	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	3	
 	 	588	
 	 	(591	)	 	—	
 	
Reduction to non-controlling interest, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(43	)	 	—	
 	 	(43	)	
Common shares issued in public offering	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	468	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	468	
 	
Adjustment for change in tax basis of property, plant and equipment, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	153	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	153	
 	
Payment of dividends to Class A common stockholders	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(5	)	 	—	
 	 	(10	)	 	—	
 	 	(15	)	
Balances at December 31, 2013	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	621	
 	 	$	8	
 	 	$	—	
 	 	$	623	
 	 	$	—	
 	 	$	1,252	
 	
Transfer of EME-NYLD-Eligible Assets  (c)	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	460	
 	 	—	
 	 	460	
 	
Net Income	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	16	
 	 	—	
 	 	48	
 	 	—	
 	 	64	
 	
Pre-acquisition net income of Drop Down Assets	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	48	
 	 	—	
 	 	48	
 	
Unrealized loss on derivatives, net of tax	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(9	)	 	(43	)	 	—	
 	 	(52	)	
Capital contributions from NRG, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	16	
 	 	—	
 	 	16	
 	
Distributions and returns of capital to NRG net of contributions, cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(84	)	 	—	
 	 	(84	)	
Payment for Acquired ROFO Assets	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(357	)	 	—	
 	 	(357	)	
Proceeds from the issuance of Class A common stock	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	630	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	630	
 	
Equity portion of the convertible debt	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	23	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	23	
 	
Common stock dividends	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(20	)	 	(21	)	 	—	
 	 	(60	)	 	—	
 	 	(101	)	
Adjustment for change in tax basis of assets acquired from NRG, non-cash	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(14	)	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	(14	)	
Balances at December 31, 2014	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	—	
 	 	$	1,240	
 	 	$	3	
 	 	$	(9	)	 	$	651	
 	 	$	—	
 	 	$	1,885	

 	

(a)Retrospectively adjusted starting on January 1, 2012, as discussed in Note 1, Nature of Business.
(b)  As previously reported.
(c)  Represents transfer of EME-NYLD-Eligible Assets, which were acquired by NRG on April 1, 2014, and acquired by the Company on January 2, 2015, as discussed in Note 1,  Nature of Business.
See accompanying notes to consolidated financial statements.

8

NRG YIELD, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 — Nature of Business
NRG Yield, Inc., or the Company, is a dividend growth-oriented company formed on December 20, 2012.The Company used the net proceeds from its initial public offering of Class A common stock on July 22, 2013 to acquire 100%, or 22,511,250, of the Class A units of NRG Yield LLC. In connection with the acquisition of the Class A units, the Company also became the sole managing member of NRG Yield LLC, thereby acquiring a controlling interest. NRG Yield LLC, through its wholly owned subsidiary, NRG Yield Operating LLC, is a holder of a portfolio of contracted renewable and conventional generation and thermal infrastructure assets, primarily located in the Northeast, Southwest and California regions of the U.S.
Prior to the secondary offering, the Company and NRG owned 34.5% and 65.5% of NRG Yield LLC, respectively. On July 29, 2014, the Company issued 12,075,000 shares of Class A common stock in a secondary offering for net proceeds, after underwriting discount and expenses, of $630 million. The Company utilized the proceeds of the offering to acquire 12,075,000 additional Class A units of NRG Yield LLC and, as a result, subsequent to the secondary offering and as of December 31, 2014, the Company owns 44.7% of NRG Yield LLC, and consolidates the results of NRG Yield LLC through its controlling interest, with NRG's 55.3% interest shown as noncontrolling interest in the financial statements. The holders of the Company's issued and outstanding shares of Class A common stock are entitled to 100% of the Company's economic interests and are entitled to dividends. NRG receives distributions from Yield LLC through its ownership of Class B common units.
On May 5, 2015, the Company's stockholders approved amendments to the Company's certificate of incorporation that resulted in the creation of two new classes of capital stock, Class C common stock and Class D common stock. The recapitalization became effective on May 14, 2015, with the split of each outstanding share of Class A common stock into one share of Class A common stock and one share of Class C common stock, and the split of each outstanding share of Class B common stock into one share of Class B common stock and one share of Class D common stock.
The Class C common stock and Class D common stock have the same rights and privileges and rank equally, share ratably and are identical in all respects to the shares of Class A common stock and Class B common stock, respectively, as to all matters, except that each share of Class C common stock and Class D common stock is entitled to 1/100th of a vote on all stockholder matters. The par value per share of the Company’s Class A common stock and Class B common stock remains unchanged at $0.01 per share after the effect of the stock split described above. Accordingly, the stock split is accounted for as a stock dividend. The Company recorded a transfer between retained earnings and common stock equal to the par value of each share of Class C common stock and Class D common stock that is issued. The Company also gave retrospective effect to prior period share and per share amounts in the audited historical consolidated financial statements for the effect of the stock dividend, such that all periods are comparable. As such, the Company's historical financial statements previously filed with the SEC have been recast in this Current Report on Form 8-K to include the retrospective effect of the stock split on all the periods reported.

As described in Note 3, Business Acquisitions, on June 30, 2014, NRG Yield Operating LLC acquired the TA High Desert, RE Kansas South, and El Segundo projects, or the Acquired ROFO Assets, from NRG for total cash consideration of $357 million plus assumed project level debt. Additionally, as described in Note 3,  Business Acquisitions , on January 2, 2015, NRG Yield Operating LLC acquired Pinnacle, Buffalo Bear and Taloga, or the Tapestry projects, as well as Laredo Ridge and Walnut Creek, or collectively, the EME-NYLD-Eligible Assets, for total cash consideration of $489 million, plus assumed project-level debt. The acquisitions of the Acquired ROFO Assets and the EME-NYLD-Eligible Assets, or collectively the Drop Down Assets, from NRG were accounted for as transfers of entities under common control by NRG and accordingly, 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 were recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. The guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. 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, which was January 1, 2013 for El Segundo, May 13, 2013, for RE Kansas South, March 28, 2013, for TA High Desert and April 1, 2014, for Laredo Ridge, Walnut Creek and Tapestry. For RE Kansas South, TA High Desert, Laredo Ridge, Walnut Creek and Tapestry, the dates represent the dates these entities were acquired by NRG. Member's equity represents NRG's equity in the subsidiaries, and accordingly, in connection with the acquisition by the Company, the balances were reclassified into noncontrolling interest. The Company's historical financial statements in all reports filed with the SEC subsequent to June 30, 2014, were previously recast to include the results attributable to the Acquired ROFO Assets. The Company's historical financial statements for and as of the year ended December 31, 2014 previously filed with the SEC have been recast in this Current Report on Form 8-K to include the results attributable to the EME-NYLD-Eligible Assets from the date these entities were under common control, or April 1, 2014.

9

                                                

 
The following table represents the structure of the Company as of December 31, 2014, with the retrospective application of the stock split that took place on May 14, 2015:        

For all periods prior to the initial public offering, the accompanying combined financial statements represent the combination of the assets that NRG Yield LLC 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" represents the accounting predecessor, or the combination of the acquired businesses. For all periods subsequent to the initial public offering, the accompanying audited consolidated financial statements represent the consolidated results of the Company, which consolidates NRG Yield LLC through its controlling interest.

10

                                                

As of December 31, 2014, the Company's operating assets are comprised of the following projects:

Projects	 	Percentage Ownership	 	Net Capacity (MW)  (a)	 	Offtake Counterparty	 	Expiration	
Conventional	 	 	 	 	 	 	 	 	
GenConn Middletown	 	49.95	%	 	95	
 	 	Connecticut Light & Power	 	2041	
GenConn Devon	 	49.95	%	 	95	
 	 	Connecticut Light & Power	 	2040	
Marsh Landing	 	100	%	 	720	
 	 	Pacific Gas and Electric	 	2023	
El Segundo	 	100	%	 	550	
 	 	Southern California Edison	 	2023	
Walnut Creek	 	100	%	 	485	
 	 	Southern California Edison	 	2023	
 	 	 	 	1,945	
 	 	 	 	 	
Utility Scale Solar	 	 	 	 	 	 	 	 	
Alpine	 	100	%	 	66	
 	 	Pacific Gas and Electric	 	2033	
Avenal	 	49.95	%	 	23	
 	 	Pacific Gas and Electric	 	2031	
Avra Valley	 	100	%	 	25	
 	 	Tucson Electric Power	 	2032	
Blythe	 	100	%	 	21	
 	 	Southern California Edison	 	2029	
Borrego	 	100	%	 	26	
 	 	San Diego Gas and Electric	 	2038	
Roadrunner	 	100	%	 	20	
 	 	El Paso Electric	 	2031	
CVSR	 	48.95	%	 	122	
 	 	Pacific Gas and Electric	 	2038	
RE Kansas South	 	100	%	 	20	
 	 	Pacific Gas and Electric	 	2033	
TA High Desert	 	100	%	 	20	
 	 	Southern California Edison	 	2033	
 	 	 	 	343	
 	 	 	 	 	
Distributed Solar	 	 	 	 	 	 	 	 	
AZ DG Solar Projects	 	100	%	 	5	
 	 	Various	 	2025 - 2033	
PFMG DG Solar Projects	 	51	%	 	5	
 	 	Various	 	2032	
 	 	 	 	10	
 	 	 	 	 	
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	 	100	%	 	137	
 	 	Southern California Edison	 	2038(c)	
Alta XI	 	100	%	 	90	
 	 	Southern California Edison	 	2038(c)	
South Trent	 	100	%	 	101	
 	 	AEP Energy Partners	 	2029	
Laredo Ridge	 	100	%	 	80	
 	 	Nebraska Public Power District	 	2031	
Taloga	 	100	%	 	130	
 	 	Oklahoma Gas & Electric	 	2031	
Pinnacle	 	100	%	 	55	
 	 	Maryland Department of General Services and University System of Maryland	 	2031	
Buffalo Bear	 	100	%	 	19	
 	 	Western Farmers Electric Co-operative	 	2033	
 	 	 	 	1,332	
 	 	 	 	 	
Thermal	 	 	 	 	 	 	 	 	
Thermal equivalent MWt(b)	 	100	%	 	1,310	
 	 	Various	 	Various	
Thermal generation	 	100	%	 	124	
 	 	Various	 	Various	
 	 	 	 	 	 	 	 	 	
Total net capacity (excluding equivalent MWt)	 	 	 	3,754	

 	

(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, 2014.
(b) 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 NRG Yield Inc.'s thermal facilities and certain of its customers.
(c) PPA begins on January 1, 2016.

11

                                                

Substantially all of the Company's generation assets are under long-term contractual arrangements for the output or capacity from these assets. The thermal assets are comprised of district energy systems and combined heat and power plants that produce steam, hot water and/or chilled water and in some instances, electricity at a central plant. Three of the district energy systems are subject to rate regulation by state public utility commissions while the other district energy systems have rates determined by negotiated bilateral contracts.
The historical combined financial statements include allocations of certain NRG corporate expenses. Management believes the assumptions and methodology underlying the allocation of general corporate overhead expenses are reasonable. The allocated costs include legal, accounting, tax, treasury, information technology, insurance, employee benefit costs, and other corporate costs. However, such expenses may not be indicative of the actual level of expense that would have been incurred if the Company had operated as an independent, publicly-traded company during the periods prior to the offering or of the costs expected to be incurred in the future. Allocations of NRG corporate expenses were $4 million for the period beginning on January 1, 2013 and ending on July 22, 2013 and $7 million for the year ended December 31, 2012. In connection with the initial public offering, the Company entered into a management services agreement with NRG for various services, including human resources, accounting, tax, legal, information systems, treasury, and risk management. Costs incurred by the Company under this agreement were $3 million for the period beginning July 23, 2013 and ending December 31, 2013 and $8 million for the year ended December 31, 2014, which included certain direct expenses incurred by NRG on behalf of the Company.
For all periods prior to the initial public offering, member's equity represents the combined equity of the Company's subsidiaries, including adjustments necessary to present the Company's financial statements as if the Company were in existence as of the beginning of the periods presented. Member's equity represents NRG's equity in the subsidiaries, and accordingly, in connection with the initial public offering, the historical equity balance as of that date was reclassified into noncontrolling interest. Subsequent to the initial public offering, stockholders' equity represents the equity associated with the Class A common stockholders, with the equity associated with the Class B common stockholders, or NRG, classified as noncontrolling interest.
Note 2 — Summary of Significant Accounting Policies 
Basis of Presentation and Principles of Consolidation
The Company's consolidated and combined financial statements have been prepared in accordance with U.S. GAAP. The Financial Accounting Standards Board, or FASB, Accounting Standards Codification, or ASC, is the source of authoritative U.S. 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 U.S. GAAP for SEC registrants.
The consolidated and combined 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.

12

                                                

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.
Restricted Cash
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. These funds are used to pay for capital expenditures, current operating expenses and current debt service payments as well as to fund required equity contributions, per the restrictions of the debt agreements.
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, 2014, and 2013.
Inventory
Inventory consists principally of spare parts and fuel oil and is valued at the lower of weighted average cost or market, unless evidence indicates that the weighted average cost will be recovered with a normal profit in the ordinary course of business. 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 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.
Additionally, the Company reduces the book value of the property, plant and equipment of its eligible renewable energy projects for any cash grants that are submitted to the U.S. Treasury Department when the receivable is recorded for the net realizable amount. The related deferred tax asset is also recorded with a corresponding reduction to the book value of the property, plant and equipment. For further discussion of these matters see Note 4,  Property, Plant and Equipment .
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 recognized 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.
Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures , or ASC 323, which requires that a loss in value of an investment that is other than a 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.
Capitalized Interest
Interest incurred on funds borrowed to finance capital projects is capitalized, until the project under construction is ready for its intended use. The amount of interest capitalized for the years ended December 31, 2014, 2013 and 2012 was less than $1 million, $18 million and $31 million, respectively.
When a project is available for operations, capitalized interest is reclassified to property, plant and equipment and amortized on a straight-line basis over the estimated useful life of the project's related assets.

13

                                                

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.
Intangible Assets
Intangible assets represent contractual rights held by NRG Yield, Inc. The Company recognizes specifically identifiable intangible assets including customer contracts, customer relationship, power purchase agreements and development rights when specific rights and contracts are acquired. These intangible assets are amortized primarily on a straight-line basis.
Notes Receivable
Notes receivable consist of receivables related to the financing of required network upgrades and a variable-rate note secured by the equity interest in a joint venture. The notes issued with respect to network upgrades will be repaid within a 5 year period following the date each facility reaches commercial operations.
Income Taxes
The Company accounts for income taxes using the liability method in accordance with ASC 740, Income Taxes, or ASC 740, which requires that it use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences.
The Company has two categories of income tax expense or benefit — current and deferred, as follows:
 	 	
•	Current income tax expense or benefit consists solely of current taxes payable less applicable tax credits, and	
 	 	
•	Deferred income tax expense or benefit is the change in the net deferred income tax asset or liability, excluding amounts charged or credited to accumulated other comprehensive income.	
The Company reports some of its revenues and expenses differently for financial statement purposes than for income tax return purposes, resulting in temporary and permanent differences between the Company's financial statements and income tax returns. The tax effects of such temporary differences are recorded as either deferred income tax assets or deferred income tax liabilities in the Company's consolidated balance sheets. The Company measures its deferred income tax assets and deferred income tax liabilities using income tax rates that are currently in effect. The Company believes it is more likely than not that the results of future operations will generate sufficient taxable income which includes the future reversal of existing taxable temporary differences to realize deferred tax assets, net of valuation allowances. A valuation allowance is recorded to reduce the net deferred tax assets to an amount that is more-likely-than-not to be realized.
The Company accounts for uncertain tax positions in accordance with ASC 740, which applies to all tax positions related to income taxes. Under ASC 740, tax benefits are recognized when it is more-likely-than-not that a tax position will be sustained upon examination by the authorities. The benefit recognized from a position that has surpassed the more-likely-than-not threshold is the largest amount of benefit that is more than 50% likely to be realized upon settlement. The Company recognizes interest and penalties accrued related to uncertain tax benefits as a component of income tax expense.
In accordance with ASC 805 and as discussed further in Note 13, Income Taxes, changes to existing net deferred tax assets or valuation allowances or changes to uncertain tax benefits, are recorded to income tax expense.

14

                                                

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. Related revenues 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. In order to determine lease classification as operating, the Company evaluates the terms of the PPA to determine if the lease includes any of the following provisions which would indicate capital lease treatment:
 	 	
•	Transfers the ownership of the generating facility,	
 	 	
•	Bargain purchase option at the end of the term of the lease,	
 	 	
•	Lease term is greater than 75% of the economic life of the generating facility, or	
 	 	
•	Present value of minimum lease payments exceed 90% of the fair value of the generating facility at inception of the lease	
In considering the above it was determined that all of Company’s PPAs are operating leases. ASC 840 requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. Judgment is required by management in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or capital lease.
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, 2014, 2013 and 2012 was $194 million, $105 million and $33 million, respectively.
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 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.

15

                                                

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. Accounts receivable, notes receivable, and derivative instruments 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 payable, intercompany accounts payable and receivable, and accrued expenses and other 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 asset retirement obligations were $27 million and $9 million for the years ended December 31, 2014, and 2013, respectively. The Company records AROs as part of other non-current liabilities on its balance sheet.
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 EPC agreements, 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, it 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 three energy projects accounted for by the equity method, one of which is a VIE, where the Company is not a primary beneficiary. 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.

16

                                                

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. 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.
Use of Estimates
The preparation of consolidated financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amounts of assets and liabilities as of the date of the financial statements. They also impact the reported amount of net earnings during the reporting period. 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, tax provisions, uncollectible accounts, environmental liabilities, acquisition accounting and legal costs incurred in connection with recorded loss contingencies, among others. 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.
Reclassifications
Certain prior-year amounts have been reclassified for comparative purposes.

17

                                                

Recent Accounting Developments
ASU 2014-16 - In November 2014, the FASB issued ASU No. 2014-16, Derivatives and Hedging (Topic 815): Determining Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or to Equity , or ASU No. 2014-16. The amendments of ASU No. 2014-16 clarify how U.S. GAAP should be applied in determining whether the nature of a host contract is more akin to debt or equity and in evaluating whether the economic characteristics and risks of an embedded feature are "clearly and closely related" to its host contract. The guidance in ASU No. 2014-16 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted. The Company is currently evaluating the impact of the standard on the Company's results of operations, cash flows and financial position.
ASU 2014-09 - In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), or ASU No. 2014-09. The amendments of ASU No. 2014-09 complete the joint effort between the FASB and the International Accounting Standards Board, or IASB, to develop a common revenue standard for U.S. GAAP and International Financial Reporting Standards, or IFRS, and to improve financial reporting. The guidance in ASU No. 2014-09 provides that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the considerations to which the entity expects to be entitled to in exchange for the goods or services provided and establishes the following steps to be applied by an entity: (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies the performance obligation. The guidance of ASU No. 2014-09 is effective for annual reporting periods beginning after December 15, 2016, including interim periods therein. Early adoption is not permitted. The Company is currently evaluating the impact of the standard on the Company's results of operations, cash flows and financial position.
ASU 2013-11 - In July 2013, the FASB issued ASU No. 2013-11, Income Taxes (Topic 740) Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists , or ASU No. 2013-11.  The amendments of ASU 2013-11, require an entity to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, as a reduction of a deferred tax asset for an NOL, a similar tax loss or tax credit carryforwards rather than a liability when the uncertain tax position would reduce the NOL or other carryforward under the tax law of the applicable jurisdiction and the entity intends to use the deferred tax asset for that purpose.  The guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The Company adopted this standard effective January 1, 2014. The adoption of this standard did not impact the Company's results of operations or cash flows as the Company has no uncertain tax benefits as of December 31, 2014.

Note 3 — Business Acquisitions 
2014 Acquisitions
Alta Wind Portfolio Acquisition — OnAugust 12, 2014, the Company acquired 100% of the membership interests of Alta Wind Asset Management Holdings, LLC, Alta Wind Company, LLC, Alta Wind X Holding Company, LLC and Alta Wind XI Holding Company, LLC, which collectively own seven wind facilities that total 947 MW located in Tehachapi, California, and a portfolio of associated land leases, or the Alta Wind Portfolio. Power generated by the Alta Wind Portfolio is sold to Southern California Edison under long-term PPAs with 21 years of remaining contract life for Alta I-V and 22 years, beginning in 2016, for Alta X and XI.
The purchase price for the Alta Wind Portfolio was $923 million, which consisted of a base purchase price of $870 million, as well as a payment for working capital of $53 million, plus the assumption of $1.6 billion of non-recourse project-level debt. In order to fund the purchase price, the Company completed an equity offering of 12,075,000 shares of its Class A common stock at an offering price of $54.00 per share on July 29, 2014, which resulted in net proceeds of $630 million, after underwriting discounts and expenses. In addition, on August 5, 2014, NRG Yield Operating LLC issued $500 million of Senior Notes, which bear interest at a rate of 5.375% and mature in August 2024.
The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The initial accounting for the business combination is not complete because the evaluation necessary to assess the fair values of certain net assets acquired is still in process. The provisional amounts are subject to revision until 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. The purchase price of $923 million was provisionally allocated as follows:

18

                                                

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Acquisition Date	 	Measurement period adjustments	 	Revised Acquisition Date	
 	 	(In millions)	
Assets	 	 	 	 	 	 	
Cash	 	$	22	
 	 	$	—	
 	 	$	22	
 	
Current and non-current assets	 	49	
 	 	—	
 	 	49	
 	
Property, plant and equipment	 	1,057	
 	 	247	
 	 	1,304	
 	
Intangible assets	 	1,420	
 	 	(243	)	 	1,177	
 	
Total assets acquired	 	2,548	
 	 	4	
 	 	2,552	

Liabilities	 	 	 	 	 	 	
Debt	 	1,591	
 	 	—	
 	 	1,591	
 	
Current and non-current liabilities	 	34	
 	 	4	
 	 	38	
 	
Total liabilities assumed	 	1,625	
 	 	4	
 	 	1,629	
 	
Net assets acquired	 	$	923	
 	 	$	—	
 	 	$	923	
 	
The Company incurred and expensed acquisition-related transaction costs related to the acquisition of the Alta Wind Portfolio of $2 million for the year ended December 31, 2014.

19

                                                

Fair value measurements
The provisional fair values of the property, plant and equipment and intangible assets at the acquisition date were measured primarily based on significant inputs that are not observable in the market and thus represent a Level 3 measurement as defined in ASC 820. Significant inputs were as follows:
 	 	
•	Property, plant and equipment— The estimated fair values were determined primarily based on an income method using discounted cash flows and validated using a cost approach based on the replacement cost of the assets less economic obsolescence. The income approach was applied by determining the enterprise value for each acquired entity and subtracting the fair value of the intangible assets and working capital to determine the implied value of the tangible fixed assets. This methodology was primarily relied upon as the forecasted cash flows incorporate the specific attributes of each asset including age, useful life, equipment condition and technology. The income approach also allows for an accurate reflection of current and expected market dynamics such as supply and demand and regulatory environment as of the acquisition date.	
 	 	
•	Intangible Assets - PPAs— The fair values of the PPAs acquired were determined utilizing a variation of the income approach where the incremental future cash flows resulting from the acquired PPAs compared to the cash flows based on current market prices were discounted to present value at a weighted average cost of capital reflective of a market participant. The values were corroborated with available market data. The PPA values will be amortized over the term of the PPAs, which approximate 22 years.	
 	 	
•	Intangible Assets - Leasehold rights— The fair values of the leasehold rights acquired, which represent the contractual right to receive royalty payments equal to a percentage of PPA revenue from certain projects, were determined utilizing the income approach. The values were corroborated with available market data. The leasehold rights values will be amortized over a period of 21 years, which is equal to the average term of the contracts.	
Supplemental Pro Forma Information
Since the acquisition date, the Alta Wind Portfolio contributed $49 million in operating revenues and $39 million in net losses. The following unaudited supplemental pro forma information represents the results of operations as if the Company had acquired the Alta Wind Portfolio on January 1, 2013:

 	 	For the year ended December 31,	
(In millions, except per share amounts)	 	2014	 	2013	
 	
Operating Revenues	 	$	821	
 	 	$	531	
 	
Net Income	 	94	
 	 	87	
 	
Net Income Attributable to NRG Yield, Inc.	 	7	
 	 	8	
 	
Earnings per Weighted Average Class A and Class C Common Share - Basic and Diluted	 	$	0.10	
 	 	$	0.12	
 	
The supplemental unaudited pro forma information has been adjusted to include the pro forma impact of depreciation of property, plant and equipment and amortization of PPAs, based on the preliminary purchase price allocations. The pro forma data has also been adjusted to reflect the additional interest expense in connection with the issuance of Senior Notes, adjustment to the non-controlling interest due to the change in NRG's ownership interest to 55.3% from 65.5% effective July 29, 2014, as well as the related tax impact. There were no transactions during the periods between NRG and the Alta Wind Portfolio. The pro forma results are presented for illustrative purposes only and do not reflect the realization of potential cost savings or any related integration costs.
Acquired ROFO Assets —On June 30, 2014, NRG Yield Operating LLC acquired from NRG: (i) El Segundo, a 550 MW fast-start, gas-fired facility located in Los Angeles County, California; (ii) TA High Desert, a 20 MW solar facility located in Los Angeles County, California; and (iii) RE Kansas South, a 20 MW solar facility located in Kings County, California. The Company paid total cash consideration of $357 million, which represents a base purchase price of $349 million and $8 million of working capital adjustments. In addition, the acquisition included the assumption of $612 million in project- level debt. The assets and liabilities transferred to the Company relate to interests under common control by NRG and accordingly, were recorded at historical cost in accordance with  ASC 805-50 . The difference between the cash proceeds and historical value of the net assets was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. Since the transaction constituted a transfer of entities under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control.

20

                                                

The following is a summary of assets and liabilities transferred in connection with the acquisition as of June 30, 2014:

 	RE Kansas South	 	TA High Desert	 	El Segundo	
 	(In millions)	
Current assets	$	1	
 	 	$	3	
 	 	$	43	
 	
Property, plant and equipment	50	
 	 	67	
 	 	625	
 	
Non-current assets	2	
 	 	13	
 	 	76	
 	
Total assets	53	
 	 	83	
 	 	744	

Debt	35	
 	 	57	
 	 	520	
 	
Other current and non-current liabilities	2	
 	 	—	
 	 	30	
 	
Total liabilities	37	
 	 	57	
 	 	550	
 	
Net assets acquired	$	16	
 	 	$	26	
 	 	$	194	
 	
The following table presents historical information summary combining the financial information for the Acquired ROFO Assets transferred in connection with the acquisition:

 	December 31, 2013	
 	As Previously Reported	 	RE Kansas South	 	TA High Desert	 	El Segundo	 	As Currently Reported	
 	 	 	(In millions)	 	 	
Current assets	$	267	
 	 	$	25	
 	 	$	28	
 	 	$	58	
 	 	$	378	
 	
Property, plant and equipment	1,541	
 	 	51	
 	 	63	
 	 	636	
 	 	2,291	
 	
Non-current assets	505	
 	 	3	
 	 	10	
 	 	51	
 	 	569	
 	
Total assets	2,313	
 	 	79	
 	 	101	
 	 	745	
 	 	3,238	

 	 	 	 	 	 	 	 	 	 	
Debt	1,133	
 	 	58	
 	 	80	
 	 	512	
 	 	1,783	
 	
Other current and non-current liabilities	169	
 	 	5	
 	 	3	
 	 	26	
 	 	203	
 	
Total liabilities	$	1,302	
 	 	$	63	
 	 	$	83	
 	 	$	538	
 	 	$	1,986	

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Year ended December 31, 2013	
 	As Previously Reported	 	RE Kansas South	 	TA High Desert	 	El Segundo	 	As Currently Reported	
 	 	 	 	
Operating revenues	$	313	
 	 	$	2	
 	 	$	8	
 	 	$	56	
 	 	$	379	
 	
Operating income	128	
 	 	1	
 	 	4	
 	 	34	
 	 	167	
 	
Net income	$	109	
 	 	$	(1	)	 	$	1	
 	 	$	23	
 	 	$	132	

2013 Acquisitions
Energy Systems — On December 31, 2013, NRG Energy Center Omaha Holdings, LLC, an indirect wholly owned subsidiary of NRG Yield LLC, acquired Energy Systems Company, or Energy Systems, for approximately $120 million. The acquisition was financed from cash on hand. Energy Systems is an operator of steam and chilled water thermal facilities that provides heating and cooling services to nonresidential customers in Omaha, Nebraska. The acquisition was recorded as a business combination under ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The purchase price was primarily allocated to property, plant and equipment of $60 million, customer relationships of $59 million, and $1 million of working capital. The accounting for Energy Systems was completed as of September 30, 2014, at which point the provisional fair values became final with no material changes.

21

                                                

2012 Acquisitions
Marsh Landing— On December 14, 2012, through its acquisition of GenOn Energy, Inc., or GenOn, NRG acquired 100% of the Marsh Landing project, a 720 MW natural gas-fueled peaking facility being constructed near Antioch, California. Immediately prior to the initial public offering, NRG transferred ownership of Marsh Landing to NRG Yield LLC. Power generated from Marsh Landing is sold to Pacific Gas & Electric, or PG&E, under a 10 year PPA. In connection with the acquisition, the Company assumed obligations under a credit agreement for up to $650 million in construction and permanent financing for the Marsh Landing generating facility. The Marsh Landing generating facility reached commercial operations on May 1, 2013.
The fair value of the net assets acquired was $138 million. The accounting for the acquisition was completed on December 13, 2013. The Company recorded a measurement period adjustment increasing the provisional fair value of the acquired property, plant and equipment by $73 million, from $537 million to $610 million. The primary driver for the revised fair value was the refinement of the methodology used to value the assets.
2015 Acquisition of EME-NYLD-Eligible Assets from NRG

On January 2, 2015, NRG Yield Operating LLC acquired the following projects from NRG: (i) Laredo Ridge, a 80 MW wind facility located in Petersburg, Nebraska, (ii) the Tapestry projects, which include Buffalo Bear, a 19 MW wind facility in Buffalo, Oklahoma, Taloga, a 130 MW wind facility in Putnum, Oklahoma, and Pinnacle, a 55 MW wind facility in Keyser, West Virginia, and (iii)  Walnut Creek, a 485 MW natural gas facility located in City of Industry, California, for total cash consideration of $489 million plus assumed project level debt of $737 million, including $9 million for working capital. The Company funded the acquisition with cash on hand and drawings under the Company's revolving credit facility. The assets and liabilities transferred to the Company relate to interests under common control by NRG and accordingly, 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 of $61 million, as well as $23 million of AOCL, were recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. Since the transaction constituted a transfer of net assets under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. The Company funded the acquisition with cash on hand and borrowings under the Company's revolving credit facility.

The following is a summary of assets and liabilities transferred in connection with the acquisition on January 2, 2015:

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

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

22

                                                

Supplemental Pro Forma Information
The following unaudited supplemental pro forma information represents the results of operations as if the Company had acquired the EME-NYLD-Eligible Assets on January 1, 2013:

 	 	For the year ended December 31,	
(In millions, except per share amounts)	 	2014	 	2013	
 	
Operating Revenues	 	$	715	
 	 	$	513	
 	
Net Income	 	97	
 	 	145	
 	
Net Income Attributable to NRG Yield, Inc.	 	21	
 	 	16	
 	
Earnings per Weighted Average Class A and Class C Common Share - Basic and Diluted	 	$	0.38	
 	 	$	0.35	

Note 4 — Property, Plant and Equipment 
The Company’s major classes of property, plant, and equipment were as follows:

 	December 31, 2014	 	December 31, 2013	 	Depreciable Lives	
 	(In millions)	 	 	
Facilities and equipment	$	4,709	
 	 	$	2,373	
 	 	2 - 40 Years	
Land and improvements	87	
 	 	86	
 	 	 	
Construction in progress	8	
 	 	6	
 	 	 	
Total property, plant and equipment	4,804	
 	 	2,465	
 	 	 	
Accumulated depreciation	(338	)	 	(174	)	 	 	
Net property, plant and equipment	$	4,466	
 	 	$	2,291	
 	 	 	
Renewable Energy Grants
The Borrego solar project achieved commercial operations on February 12, 2013 and transferred the construction in progress to property, plant and equipment. On May 16, 2013, the Borrego solar project, as a qualified renewable energy project, applied for a cash grant in lieu of investment tax credit from the U.S. Treasury Department in the amount of $39 million. A receivable for the cash grant was recorded when the application was filed, which resulted in a reduction to the book basis of the property, plant and equipment. In addition, the receivable was reduced to $36 million as a result of the federal government’s sequestration, which was put into effect on March 1, 2013. The related deferred tax asset of $10 million was recorded with a corresponding reduction of the book value of Borrego’s property, plant and equipment. In March 2014, the Company received payment of $30 million for the cash grant related to Borrego. The Company recorded a reserve for the shortage pending further discussions with the US treasury Department .
The TA High Desert solar project achieved commercial operations on March 25, 2013 and transferred the construction in progress to property, plant and equipment. On May 22, 2013, the TA High Desert solar project, as a qualified renewable energy project, applied for a cash grant in lieu of investment tax credit from the U.S. Treasury Department in the amount of $25 million. A receivable for the cash grant was recorded when the application was filed, which resulted in a reduction to the book basis of the property, plant and equipment. In addition, the receivable was reduced to $20 million as a result of the federal government’s sequestration, which was put into effect on March 1, 2013. The related deferred tax asset of $6 million was recorded with a corresponding reduction of the book value of TA High Desert's property, plant and equipment. In April 2014, TA High Desert received a payment of $20 million for the cash grant and reduced the book value of its property, plant and equipment by the amount by which the grant was reduced.

23

                                                

The RE Kansas South solar project achieved commercial operations on June 7, 2013, and transferred the construction in progress to property, plant and equipment. On June 27, 2013, the RE Kansas South solar project, as a qualified renewable energy project, applied for a cash grant in lieu of investment tax credit from the U.S. Treasury Department in the amount of $23 million. A receivable for the cash grant was recorded when the application was filed, which resulted in a reduction to the book basis of the property, plant and equipment. In addition, the receivable was reduced to $21 million as a result of the federal government’s sequestration, which was put into effect on March 1, 2013. The related deferred tax asset of $6 million was recorded with a corresponding reduction of the book value of RE Kansas South's property, plant and equipment. In April 2014, RE Kansas South received a payment of $21 million for the cash grant.

Note 5 — Investments Accounted for by the Equity Method and Variable Interest Entities
Equity Method Investments
Avenal—The Company owns a 49.95% equity interest in Avenal, which consists of three solar PV projects in Kings County, California, approximately 45 MWs, all of which became commercially operational during the third quarter of 2011. NRG retained a 0.05% interest and Eurus Energy owns the remaining 50% of Avenal. Power generated by the projects is sold under a 20-year PPA. On September 22, 2010, Avenal entered into a $35 million promissory note facility with the Company. Amounts drawn under the promissory note facility accrue interest at 4.5% per annum. As of December 31, 2013, the amount outstanding under the facility was $2 million. The facility was repaid in January 2014. Also, on September 22, 2010, Avenal entered into a $209 million financing arrangement with a syndicate of banks, or the Avenal Facility. As of December 31, 2014, and 2013, Avenal had outstanding $107 million and $112 million, respectively, under the Avenal Facility. As of December 31, 2014, the Company had an $11 million equity investment in Avenal.
CVSR—The Company owns 48.95% of CVSR, located in San Luis Obispo, California, totaling 250 MW, while NRG continues to own the remaining 51.05% of CVSR. Power generated by the project is sold under a 25-year PPA. As of December 31, 2014, the Company had a $102 million equity investment in CVSR.
In 2011, High Plains Ranch II, LLC, the direct owner of CVSR, entered into the CVSR Financing Agreement with the FFB to borrow up to $1.2 billion to fund the costs of constructing the solar facility. The CVSR Financing Agreement matures in 2037 and the loans provided by the FFB are guaranteed by the U.S. DOE. Amounts borrowed under the CVSR Financing Agreement accrue interest at a fixed rate based on U.S. Treasury rates plus a spread of 0.375%  and are secured by the assets of CVSR. As of December 31, 2014, and 2013, $815 million and $1,104 million, respectively, were outstanding under the loan. In 2012 and 2013, CVSR submitted applications to the U.S. Treasury Department for cash grants as each phase of the project began commercial operations.  In January 2014, the U.S. Treasury Department awarded cash grants on the CVSR project of $307 million ($285 million net of sequestration), which is approximately 75% of the cash grant amount for which the Company had applied. The cash grant proceeds were used to pay the outstanding balance of the bridge loan due in February 2014 and the remaining amount was used to pay a portion of the outstanding balance on the bridge loan due in August 2014. The remaining balance of the bridge loan due in August 2014 was paid by SunPower. CVSR is evaluating the basis for the U.S. Treasury Department’s award and all of its options for recovering the amount by which the U.S. Treasury Department reduced the CVSR cash grant award.
The following table presents summarized financial information for CVSR:

 	Year Ended December 31,	
 	2014	 	2013	 	2012	
Income Statement Data:	(In millions)	
Operating revenues	$	82	
 	 	$	47	
 	 	$	2	
 	
Operating income	40	
 	 	22	
 	 	1	
 	
Net income	17	
 	 	4	
 	 	1	

 	 	 	As of December 31,	
 	 	 	2014	 	2013	
 	 	 	(In millions)	
Balance Sheet Data:	 	 	 	 	 	
Current assets	$	173	
 	 	$	455	
 	
Non-current assets	868	
 	 	932	
 	
Current liabilities	33	
 	 	412	
 	
Non-current liabilities	799	
 	 	769	

24

                                                

Variable Interest Entities, or VIEs
GenConn Energy LLC — The Company has a 49.95% interest in GCE Holding LLC, the owner of GenConn Energy LLC, or GenConn, which owns and operates two 190 MW peaking generation facilities in Connecticut at the Devon and Middletown sites. Each of these facilities was constructed pursuant to a 30-year cost of service type contract with the Connecticut Light & Power Company. All four units at the GenConn Devon facility reached commercial operation in June 2010 and were released to the ISO-NE by July 2010. In June 2011, all four units at the GenConn Middletown facility reached commercial operation and were released to the ISO-NE. GenConn is considered a VIE under ASC 810, however the Company is not the primary beneficiary, and accounts for its investment under the equity method.
The project was funded through equity contributions from the owners and non-recourse, project level debt. As of December 31, 2014, the Company's investment in GenConn was $114 million and its maximum exposure to loss is limited to its equity investment. On September 17, 2013, GenConn refinanced its existing project financing facility. The refinanced facility is comprised of a $237 million note with an interest rate of 4.73% and a maturity date of July 2041 and a 5-year, $35 million working capital facility that matures in 2018 which can be used to issue letters of credit at an interest rate of 1.875% per annum. As of December 31, 2014 $228 million was outstanding under the note and nothing was drawn on the working capital facility. The refinancing is secured by all of the GenConn assets.
The following table presents summarized financial information for GCE Holding LLC:

 	Year ended December 31,	
 	2014	 	2013	 	2012	
Income Statement Data:	(In millions)	
Operating revenues	$	82	
 	 	$	80	
 	 	$	78	
 	
Operating income	40	
 	 	44	
 	 	45	
 	
Net income	28	
 	 	31	
 	 	29	

 	
 	 	 	 	 	 	 	 	
 	December 31, 2014	 	December 31, 2013	
Balance Sheet Data:	(In millions)	
Current assets	$	33	
 	 	$	32	
 	
Non-current assets	438	
 	 	454	
 	
Current liabilities	20	
 	 	18	
 	
Non-current liabilities	223	
 	 	232	

The following table presents undistributed equity earnings for the Company's three equity method investments:

 	As of December 31,	
 	2014	 	2013	
 	(In millions)	
Undistributed earnings from equity investments	$	22	
 	 	$	19	

25

                                                

Note 6 — Fair Value of Financial Instruments 
For cash and cash equivalents, restricted cash, accounts receivable, accounts payable, intercompany accounts payable and receivable, 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, 2014	 	As of December 31, 2013	
 	Carrying Amount	 	Fair Value	 	Carrying Amount	 	Fair Value	
 	(In millions)	
Assets:	 	 	 	 	 	 	 	
Notes receivable, including current portion — affiliate	$	—	
 	 	$	—	
 	 	$	2	
 	 	$	2	
 	
Notes receivable, including current portion	21	
 	 	21	
 	 	27	
 	 	27	
 	
Liabilities:	 	 	 	 	 	 	 	
Long-term debt, including current portion	4,787	
 	 	4,873	
 	 	1,783	
 	 	1,785	
 	
The fair value of notes receivable and long-term debt are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments and are classified as Level 3 within the fair value hierarchy.
Fair Value Accounting under ASC 820
ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:
 	 	
•	Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date.	
 	 	
•	Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.	
 	 	
•	Level 3—unobservable inputs for the asset or liability only used when there is little, if any, market activity for the asset or liability at the measurement date.	
In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement.
Recurring Fair Value Measurements
The Company records its derivative assets and liabilities at fair market value on its consolidated balance sheet. The following table presents assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:

 	As of December 31, 2014	
 	Fair Value (a)	
(In millions)	Level 2	
Derivative assets:	 	
Commodity contracts	$	—	
 	
Interest rate contracts	2	
 	
Total assets	$	2	
 	
Derivative liabilities:	 	
Commodity contracts	$	3	
 	
Interest rate contracts	114	
 	
Total liabilities	$	117	
 	
(a) There were no assets or liabilities classified as Level 1 or Level 3 as of December 31, 2014.

26

                                                

 	
 	 	 	 	 	 	 	 	 	 	 	 	
 	As of December 31, 2013	
 	Fair Value (a)	
(In millions)	Level 2	 	Level 3	 	Total	
Derivative assets:	 	 	 	 	 	
Commodity contracts	$	1	
 	 	$	—	
 	 	$	1	
 	
Interest rate contracts	20	
 	 	—	
 	 	20	
 	
Total assets	21	
 	 	—	
 	 	21	
 	
Derivative liabilities:	 	 	 	 	 	
Commodity contracts	1	
 	 	1	
 	 	2	
 	
Interest rate contracts	45	
 	 	—	
 	 	45	
 	
Total liabilities	$	46	
 	 	$	1	
 	 	$	47	
 	
(a) There were no assets or liabilities classified as Level 1 as of December 31, 2013.
There were no transfers during the years ended December 31, 2014 and 2013, between Levels 1 and 2. The following table reconciles, for the year ended December 31, 2014, the beginning and ending balances for derivative instruments that are recognized at fair value in the consolidated financial statements, at least annually, using significant unobservable inputs:

 	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)	
(In millions)	Year ended December 31, 2014	
 	Derivatives	
Beginning balance	$	(1	)	
Total gains and losses (realized/unrealized) included in earnings	1	
 	
Ending balance as of December 31, 2014	$	—	
 	
There have been no transfers in and/or out of Level 3 during the year ended December 31, 2014.

Derivative Fair Value Measurements
A majority of the Company's contracts are non-exchange-traded and valued using prices provided by external sources. For the Company’s energy markets, management receives quotes from multiple sources. To the extent that multiple quotes are received, the prices reflect the average of the bid-ask mid-point prices obtained from all sources believed to provide the most liquid market for the commodity. The remainder of the assets and liabilities represent contracts for which external sources or observable market quotes are not available. These contracts are valued using various valuation techniques including but not limited to internal models that apply fundamental analysis of the market and corroboration with similar markets. As of December 31, 2014, there were no contracts valued with prices provided by models and other valuation techniques.
The fair value of each contract is discounted using a risk free interest rate. In addition, a credit reserve is applied to reflect credit risk, which is calculated based on credit default swaps. To the extent that the net exposure is an asset, the Company uses the counterparty’s default swap rate. If the exposure is a liability, the Company uses its default swap rate. The credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of December 31, 2014, the credit reserve resulted in a $1 million increase in fair value which is a gain in OCI. It is possible that future market prices could vary from those used in recording assets and liabilities and such variations could be material.
Concentration of Credit Risk
In addition to the credit risk discussion as disclosed in Note 2, Summary of Significant Accounting Policies, 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) a 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.

27

                                                

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, 2014, credit risk exposure to these counterparties attributable to the Company's ownership interests was approximately $2.2 billion for the next five years. The majority of these power contracts are with utilities with strong credit quality and public utility commission or other regulatory support, as further described in Note 12, Segment Reporting.  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 effective portion of the change in fair value of the derivatives to accumulated OCI, until the hedged transactions occur and are recognized in earnings. The ineffective portion of a cash flow hedge is immediately 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 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 purchases for the operation of its subsidiaries. At December 31, 2014, the Company had forward and financial contracts for the purchase/sale of electricity and related products economically hedging the Company's district energy centers' forecasted output or load obligations through 2015. The Company also had forward contracts for the purchase of fuel commodities relating to the forecasted usage of the district energy centers through 2017. At December 31, 2014, these contracts were not designated as cash flow or fair value hedges.
Also, as of December 31, 2014, 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 2038, and	
 	 	
•	Natural gas transportation contracts through 2028.	
Interest Rate Swaps
The Company is exposed to changes in interest rates through the issuance of variable and fixed rate debt. In order to manage interest rate risk, it enters into interest rate swap agreements.
As of December 31, 2014, the Company had interest rate derivative instruments on non-recourse debt extending through 2031, some 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, 2014, and 2013.

 	 	 	Total Volume	
 	 	 	December 31, 2014	 	December 31, 2013	
Commodity	Units	 	(In millions)	
Natural Gas	MMBtu	 	2	
 	 	2	
 	
Interest	Dollars	 	$	2,817	
 	 	$	1,234	
 	
The increase in the interest rate position was primarily the result of the interest rate swaps acquired with the Alta Wind Portfolio.

28

                                                

Fair Value of Derivative Instruments
The following table summarizes the fair value within the derivative instrument valuation on the balance sheet:

 	Fair Value	
 	Derivative Assets	 	Derivative Liabilities	
 	December 31, 2014	 	December 31, 2013	 	December 31, 2014	 	December 31, 2013	
 	(In millions)	
Derivatives Designated as Cash Flow Hedges:	 	 	 	 	 	 	 	
Interest rate contracts current	$	—	
 	 	$	—	
 	 	$	40	
 	 	$	26	
 	
Interest rate contracts long-term	2	
 	 	14	
 	 	49	
 	 	16	
 	
Total Derivatives Designated as Cash Flow Hedges	2	
 	 	14	
 	 	89	
 	 	42	
 	
Derivatives Not Designated as Cash Flow Hedges:	 	 	 	 	 	 	 	
Interest rate contracts current	—	
 	 	—	
 	 	5	
 	 	3	
 	
Interest rate contracts long-term	—	
 	 	6	
 	 	20	
 	 	—	
 	
Commodity contracts current	—	
 	 	1	
 	 	3	
 	 	2	
 	
Total Derivatives Not Designated as Cash Flow Hedges	—	
 	 	7	
 	 	28	
 	 	5	
 	
Total Derivatives	$	2	
 	 	$	21	
 	 	$	117	
 	 	$	47	
 	
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, 2014, there was no outstanding collateral paid or received. The following table summarizes the offsetting of derivatives by counterparty master agreement level:

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

 	 	 	 	 	 	 	 	 	 	 	 	
 	Gross Amounts Not Offset in the Statement of Financial Position	
As of December 31, 2013	Gross Amounts of Recognized Assets/Liabilities	 	Derivative Instruments	 	Net Amount	
Commodity contracts:	(In millions)	
Derivative assets	$	1	
 	 	$	—	
 	 	$	1	
 	
Derivative liabilities	(2	)	 	—	
 	 	(2	)	
Total commodity contracts	(1	)	 	—	
 	 	(1	)	
Interest rate contracts:	 	 	 	 	 	
Derivative assets	20	
 	 	(12	)	 	8	
 	
Derivative liabilities	(45	)	 	12	
 	 	(33	)	
Total interest rate contracts	(25	)	 	—	
 	 	(25	)	
Total derivative instruments	$	(26	)	 	$	—	
 	 	$	(26	)	

29

                                                

Accumulated Other Comprehensive Loss
The following table summarizes the effects on the Company’s accumulated other comprehensive loss, or OCL, balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax:

 	Year ended December 31,	
 	2014	 	2013	 	2012	
 	(In millions)	
Accumulated OCL beginning balance	$	—	
 	 	$	(48	)	 	$	(28	)	
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	13	
 	 	13	
 	 	5	
 	
Mark-to-market of cash flow hedge accounting contracts	(65	)	 	35	
 	 	(25	)	
Accumulated OCL ending balance, net of income tax benefit of $6, $1 and $17, respectively	$	(52	)	 	$	—	
 	 	$	(48	)	
Accumulated OCL attributable to NRG	(43	)	 	—	
 	 	 	
Accumulated OCL attributable to NRG Yield, Inc.	$	(9	)	 	$	—	
 	 	 	
Losses expected to be realized from OCL during the next 12 months, net of income tax of $3	$	(27	)	 	

 	
 	
Impact of Derivative Instruments on the Statements of Operations
The Company has interest rate derivative instruments that are not designated as cash flow hedges as well as ineffectiveness on cash flow hedge derivatives. The effect of interest rate hedges is recorded to interest expense. For the years ended December 31, 2014 and 2013, the impact to the consolidated statements of operations was a loss of $22 million and a gain of $13 million, respectively.

The Company’s derivative commodity contracts relate to its Thermal business for the purchase of fuel commodities based on the forecasted usage of the Thermal district energy centers. Realized gains and losses on these contracts are reflected in the fuel costs that are permitted to be billed to customers through the related customer contracts or tariffs and accordingly, no gains or losses are reflected in the statement of operations for these contracts.
See Note 6, Fair Value of Financial Instruments, for discussion regarding concentration of credit risk.

30

                                                

Note 8 — Intangible Assets 
Intangible Assets — The Company's intangible assets as of December 31, 2014, and 2013 primarily reflect intangible assets established from its business acquisitions and are comprised of the following:
 	 	
•	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 NO x  allowances amortized on a straight-line basis and SO 2  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.	
 	 	
•	Customer contracts — Established with the acquisition of Northwind 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.	
 	 	
•	Customer relationships — Established with the acquisition of Northwind Phoenix and Energy Systems, 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.	
 	 	
•	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 will be 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 will be amortized on a straight-line basis.	
 	 	
•	Other — Consists 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.	
The following tables summarize the components of intangible assets subject to amortization:

Year ended December 31, 2014	Emission Allowances	 	Development
Rights	 	Customer Contracts	 	Customer
Relationships	 	PPAs	 	Leasehold Rights	 	Other	 	Total	
 	 	 	(In millions)	
January 1, 2014	$	8	
 	 	$	4	
 	 	$	15	
 	 	$	66	
 	 	$	14	
 	 	$	—	
 	 	$	3	
 	 	$	110	
 	
Acquisition of Alta Wind Portfolio	—	
 	 	—	
 	 	—	
 	 	—	
 	 	1,091	
 	 	86	
 	 	—	
 	 	1,177	
 	
Transfer of EME-NYLD-Eligible Assets	7	
 	 	—	
 	 	—	
 	 	—	
 	 	160	
 	 	—	
 	 	—	
 	 	167	
 	
Other	1	
 	 	—	
 	 	—	
 	 	—	
 	 	4	
 	 	—	
 	 	—	
 	 	5	
 	
December 31, 2014	16	
 	 	4	
 	 	15	
 	 	66	
 	 	1,269	
 	 	86	
 	 	3	
 	 	1,459	
 	
Less accumulated amortization	—	
 	 	(1	)	 	(5	)	 	(2	)	 	(26	)	 	(2	)	 	—	
 	 	(36	)	
Net carrying amount	$	16	
 	 	$	3	
 	 	$	10	
 	 	$	64	
 	 	$	1,243	
 	 	$	84	
 	 	$	3	
 	 	$	1,423	

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Year ended December 31, 2013	Emission
Allowances	 	Development Rights	 	Customer Contracts	 	Customer Relationships	 	PPAs	 	Leasehold Rights	 	Other	 	Total	
 	(In millions)	
January 1, 2013	$	8	
 	 	$	4	
 	 	$	15	
 	 	$	7	
 	 	$	4	
 	 	$	—	
 	 	$	3	
 	 	$	41	
 	
Business acquisition/transfer	—	
 	 	—	
 	 	—	
 	 	59	
 	 	10	
 	 	—	
 	 	—	
 	 	69	
 	
December 31, 2013	8	
 	 	4	
 	 	15	
 	 	66	
 	 	14	
 	 	—	
 	 	3	
 	 	110	
 	
Less accumulated amortization	—	
 	 	(1	)	 	(4	)	 	(1	)	 	(1	)	 	—	
 	 	—	
 	 	(7	)	
Net carrying amount	$	8	
 	 	$	3	
 	 	$	11	
 	 	$	65	
 	 	$	13	
 	 	$	—	
 	 	$	3	
 	 	$	103	

31

                                                

The Company recorded amortization of $29 million, $4 million and $1 million during the years ended December 31, 2014, 2013 and 2012. Of these amounts, $28 million for the year ended December 31, 2014 was recorded as contra-revenue reflecting the amortization of the fair value of the acquired intangible assets. The following table presents estimated amortization of the Company's intangible assets for each of the next five years:

Year Ended December 31,	 	Total	
 	 	(In millions)	
2015	 	$	58	
 	
2016	 	71	
 	
2017	 	71	
 	
2018	 	71	
 	
2019	 	72	
 	
The weighted average amortization period related to the intangibles acquired in the year ended December 31, 2014 was 22 years for power purchase agreements and 21 years for leasehold rights.
Out-of-market contracts — The out-of-market contract liability represents the out-of-market value of the PPA for the Blythe solar project and the out-of-market value of the land lease for Alta Wind XI Holding Company, LLC, as of their respective acquisition dates. The Blythe solar project's liability of $5 million is recorded to other non-current liabilities and is amortized to revenue on a units-of-production basis over the twenty-year term of the agreement. The Alta Wind XI Holding Company, LLC's liability of $5 million is recorded to other non-current liabilities and is amortized to cost of operations on a straight-line basis over the term of the land lease. At December 31, 2014, accumulated amortization of out-of-market contracts was $2 million and amortization expense was less than $1 million for the year ended December 31, 2014.

32

                                                

Note 9 — Long-term Debt 
The Company's borrowings, including short term and long term portions consisted of the following:

 	December 31, 2014	 	December 31, 2013	 	Interest rate % (a)	
 	(In millions, except rates)	
Convertible Notes, due 2019 (b)	$	326	
 	 	—	
 	 	3.50	
Senior Notes, due 2024	500	
 	 	—	
 	 	5.375	
Project-level debt:	 	 	 	 	 	
Alta Wind I, lease financing arrangement, due 2034	261	
 	 	—	
 	 	7.015	
Alta Wind II, lease financing arrangement, due 2034	205	
 	 	—	
 	 	5.696	
Alta Wind III, lease financing arrangement, due 2034	212	
 	 	—	
 	 	6.067	
Alta Wind IV, lease financing arrangement, due 2034	138	
 	 	—	
 	 	5.938	
Alta Wind V, lease financing arrangement, due 2035	220	
 	 	—	
 	 	6.071	
Alta Wind X, due 2021	300	
 	 	—	
 	 	L+2.00	
Alta Wind XI, due 2021	191	
 	 	—	
 	 	L+2.00	
Alta Realty Investments, due 2031	34	
 	 	—	
 	 	7.00	
Alta Wind Asset Management, due 2031	20	
 	 	—	
 	 	L+2.375	
NRG West Holdings LLC, due 2023	506	
 	 	512	
 	 	L+2.25 - L+2.875; L+2.25 - L+2.75	
NRG Marsh Landing LLC, due 2017 and 2023	464	
 	 	473	
 	 	L+ 1.75 - L+1.875; L+2.75 - L+3.00	
Walnut Creek Energy LLC, due 2023	391	
 	 	—	
 	 	L+1.625	
Tapestry Wind LLC, due 2021	192	
 	 	—	
 	 	L+1.625	
NRG Solar Alpine LLC, due 2014 and 2022	163	
 	 	221	
 	 	L+1.75 - L+2.50; L+2.25 - L+2.50	
NRG Energy Center Minneapolis LLC, due 2017 and 2025	121	
 	 	127	
 	 	5.95 -7.31	
Laredo Ridge LLC, due 2026	108	
 	 	—	
 	 	L+1.875	
NRG Solar Borrego LLC, due 2024 and 2038	75	
 	 	78	
 	 	L+ 2.50/5.65	
South Trent Wind LLC, due 2020	65	
 	 	69	
 	 	L+2.75;L+2.625	
NRG Solar Avra Valley LLC, due 2031	63	
 	 	63	
 	 	L+1.75; L+2.25	
TA High Desert LLC, due 2023 and 2033	55	
 	 	80	
 	 	L+2.50/5.15	
WCEP Holdings LLC, due 2023	46	
 	 	—	
 	 	L+3.00	
NRG Roadrunner LLC, due 2031	42	
 	 	44	
 	 	L+2.01	
NRG Solar Kansas South LLC, due 2031	35	
 	 	58	
 	 	L+2.00;L+2.625	
NRG Solar Blythe LLC, due 2028	22	
 	 	24	
 	 	L+2.75	
PFMG and related subsidiaries financing agreement, due 2030	31	
 	 	32	
 	 	6.00	
NRG Energy Center Princeton LLC, due 2017	1	
 	 	2	
 	 	5.95	
Subtotal project-level debt:	3,961	
 	 	1,783	
 	 	 	
Total debt	4,787	
 	 	1,783	
 	 	 	
Less current maturities	214	
 	 	214	
 	 	 	
Total long-term debt	$	4,573	
 	 	$	1,569	

 	

(a) As of December 31, 2014, L+ equals 3 month LIBOR plus x%, except for RE Kansas South where L+ equals 6 month LIBOR plus x%.
(b) Net of discount of $19 million as of December 31, 2014.
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 arrangement. As of December 31, 2014, the Company was in compliance with all of the required covenants.

33

                                                

The discussion below lists changes to or additions of long term debt for the year ended December 31, 2014.
NRG Yield, Inc. Convertible Notes
During the first quarter of 2014, the Company closed on its offering of $345 million of Convertible Notes. The Convertible Notes bear interest of 3.50% and mature in February 2019.  Interest on the Convertible Notes is payable semi-annually in arrears on February 1 and August 1 of each year, commencing on August 1, 2014. The Convertible Notes are convertible, under certain circumstances, into the Company’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 an initial conversion rate of approximately 21.4822 shares of Class A common stock per $1,000 principal amount of Convertible Notes. The Convertible Notes mature on February 1, 2019, unless earlier repurchased or converted in accordance with their terms. Prior to the close of business on the business day immediately preceding August 1, 2018, the Convertible Notes will be convertible only upon the occurrence of certain events and during certain periods, and thereafter, at any time until the close of business on the second scheduled trading day immediately preceding the maturity date. The Convertible Notes are guaranteed by NRG Yield Operating LLC and NRG Yield LLC.
The Convertible Notes are accounted for in accordance with ASC 470-20, Debt with Conversion and Other Options. Under ASC 470-20, issuers of convertible debt instruments that may be settled in cash upon conversion, including partial cash settlement, are required to separately account for the liability (debt) and equity (conversion option) components. The application of ACS 470-20 resulted in the recognition of $23 million as the value for the equity component with the offset to debt discount. The debt discount is amortized to interest expense using the effective interest method through February 2019.
As of December 31, 2014, the Convertible Notes were trading at approximately 114% of their face value, resulting in a total market value of $395 million compared to a carrying value of $326 million. The actual conversion value of the Convertible Notes is based on the product of the conversion rate and the market price of the Company's common stock, as defined in the Convertible Debt indenture. As of December 31, 2014, the Company's common stock closed at $47.14 per share, resulting in a pro forma conversion value for the Convertible Notes of approximately $349 million.
During the years ended December 31, 2014, the Company recorded the following expense in relation to the Convertible Notes at the effective rate of 5.00%:

(In millions)	 	 	
Interest expense at 3.5% coupon rate	 	11	
 	
Debt discount amortization	 	4	
 	
Debt issuance costs amortization	 	1	
 	
 	 	$	16	

NRG Yield Operating LLC Senior Notes
On August 5, 2014, NRG Yield Operating LLC issued $500 million of senior unsecured notes, or the Senior Notes. The Senior Notes bear interest at 5.375% and mature in August 2024. Interest on the notes is payable semi-annually on February 15 and August 15 of each year, and commenced on February 15, 2015. The Senior Notes are senior unsecured obligations of NRG Yield Operating LLC and are guaranteed by NRG Yield LLC, and by certain of NRG Yield Operating LLC’s wholly owned current and future subsidiaries.
NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility
In connection with the Company's initial public offering of Class A common stock in July 2013, as further described in Note 1,  Nature of Business , NRG Yield LLC and NRG Yield Operating LLC entered into a senior secured revolving credit facility, or the Yield Credit Facility, which provided a revolving line of credit of $60 million. On April 25, 2014, NRG Yield LLC and NRG Yield Operating LLC amended the revolving credit facility to increase the available line of credit to $450 million and extend its maturity to April 2019. The Company's revolving credit facility can be used for cash or for the issuance of letters of credit. There was no cash drawn and $38 million of letters of credit issued in support of the obligations of the Alta Wind Portfolio under the revolving credit facility as of December 31, 2014.
On January 2, 2015, the Company borrowed $210 million under the Yield Credit Facility to fund the acquisition of Walnut Creek, Laredo Ridge and the Tapestry projects. On February 2, 2015 the Company made an optional repayment of $15 million of principal and interest.

34

                                                

Project - level Debt
NRG West Holdings Credit Agreement
On August 23, 2011, NRG West Holdings LLC, or West Holdings, entered into a credit agreement with a group of lenders in respect to the El Segundo project, or the West Holdings Credit Agreement. The West Holdings Credit Agreement is comprised of a $540 million two tranche construction loan facility with additional facilities for the issuance of letters of credit or working capital loans and is secured by the assets of West Holdings.
The two tranche construction loan facility consists of the $480 million Tranche A Construction Facility, or the Tranche A Facility, and the $60 million Tranche B Construction Facility, or the Tranche B Facility. The Tranche A and Tranche B Facilities, which mature in August 2023, convert to a term loan and have an interest rate of 3-month LIBOR, plus an applicable margin which (i) increases by 0.125%  periodically from conversion through year eight for the Tranche A Facility, and (ii) increases by (a) 0.125%  upon term conversion and on the third and sixth anniversary of the term conversion and (b) by 0.250%  on the eighth anniversary of the term conversion for the Tranche B Facility. The Tranche A and Tranche B Facilities amortize based upon a predetermined schedule over the term of the loan with the balance payable at maturity. The construction loan converted to a term loan on January 28, 2014.
The West Holdings Credit Agreement also provides for the issuance of letters of credit and working capital loans to support the El Segundo project's collateral needs. This includes letter of credit facilities on behalf of West Holdings of up to $90 million in support of the PPA, up to $48 million in support of the collateral agent, and a working capital facility which permits loans or the issuance of letters of credit of up to $10 million.
As of December 31, 2014, under the West Holdings Credit Agreement, West Holdings had $447 million outstanding under the Tranche A Facility, $59 million under the Tranche B Facility, issued a $33 million letter of credit in support of the PPA, a $48 million letter in support of debt service and a $1 million letter of credit under the working capital facility.
Alpine Financing
On March 16, 2012, NRG Solar Alpine LLC, or Alpine, entered into a credit agreement with a group of lenders for a $166 million construction loan that was convertible to a term loan upon completion of the project and a $68 million cash grant loan. On January 15, 2013, the credit agreement was amended reducing the cash grant loan to $63 million. On March 26, 2013, Alpine met the conditions under the credit agreement to convert the construction loan to a term loan. Immediately prior to the conversion, the Company drew an additional $164 million under the construction loan and $62 million under the cash grant loan. The term loan amortizes on a predetermined schedule with final maturity in November 2022.
In January 2014, Alpine repaid the $62 million of outstanding cash grant loan, including accrued interest and breakage fees, with the proceeds that it had received from the U.S. Treasury Department. On June 24, 2014, Alpine amended the credit agreement to increase its term loan borrowings by an additional $13 million and to reduce the related interest rate to 3 month LIBOR plus 1.75% through June 30, 2019 and 3 month LIBOR plus 2.00% through November 2022. The proceeds were utilized to make a distribution of $11 million to NRG Yield Operating LLC with the remaining $2 million utilized to fund the costs of the amendment.
Borrego Financing
On March 28, 2013, NRG Solar Borrego I LLC, or Borrego, entered into a credit agreement with a group of lenders, or the Borrego Financing Agreement, for $45 million of 5.65% fixed rate notes and a $36 million term loan. The term loan has an interest rate of 3 month LIBOR plus an applicable margin of 2.50%, which escalates 0.25% on the fourth and eighth anniversary of the closing date. The fixed rate notes mature in February 2038 and the term loan matures in December 2024. Both amortize based upon predetermined schedules. The Borrego Financing Agreement also includes a letter of credit facility on behalf of Borrego of up to $5 million. Borrego pays an availability fee of 100% of the applicable margin on issued letters of credit. As of December 31, 2014, $45 million was outstanding under the fixed rate notes, $30 million was outstanding under the term loans, and $5 million of letters of credit in support of the project were issued.
Under the terms of the Borrego Financing Agreement on March 28, 2013, Borrego was required to enter into two fixed for floating interest rate swaps that would fix the interest rate for a minimum of 75% of the outstanding notional amount. Borrego will pay its counterparty the equivalent of a 1.125% fixed interest payment on a predetermined notional value, and quarterly, Borrego will receive the equivalent of a floating interest payment based on a 3 month LIBOR calculated on the same notional value through June 30, 2020. All interest rate swap payments by Borrego and its counterparties are made quarterly and the LIBOR rate is determined in advance of each interest period. The original notional amount of the swaps, which became effective April 3, 2013, was $15 million and will amortize in proportion to the term loan.

35

                                                

Marsh Landing Credit Agreement Term Conversion
In May 2013, Marsh Landing met the conditions under the credit agreement to convert the construction loan for the facility to a term loan which will amortize on a predetermined basis. Prior to term conversion, Marsh Landing drew the remaining funds available under the facility in order to pay costs due for construction. Marsh Landing issued a $24 million letter of credit under the facility in support of its debt service requirements. As of December 31, 2014, $108 million was outstanding under the Tranche A loan, $356 million was outstanding under the Tranche B loans, and $22 million of letters of credit in support of the project were issued.
On July 17, 2014, Marsh Landing amended its credit agreement to increase its borrowings by $34 million and to reduce the related interest rate for the Tranche A borrowings from 3 month LIBOR plus an applicable margin of 2.75% to 3 month LIBOR plus 1.75% through December 2017; and for the Tranche B to reduce the related interest rate from 3 month LIBOR plus 3.00% to 3 month LIBOR plus 1.875% through December 2017 and to 3 month LIBOR plus 2.125% through December 2020 and to 3 month LIBOR plus 2.375% thereafter. The proceeds from the borrowings were utilized to make a distribution of $29 million to NRG Yield Operating LLC and to fund the costs of the amendment.
TA High Desert Facility
The TA High Desert Facility is comprised of $53 million of fixed rate notes due 2033 at an interest rate of 5.15%, $7 million of floating rate notes due 2023, $22 million of bridge notes due the earlier of ten days after receipt of the cash grant or May 2014, and a revolving facility of $12 million. The floating rate notes have an interest rate of 3 month LIBOR plus 2.5% with LIBOR floor of 1.5%, while the bridge notes have an interest rate of 1 month LIBOR plus 2.50%. As described in Note 4, Property, Plant and Equipment , in April 2014, TA High Desert received payment of $20 million for its cash grant and utilized the proceeds, along with an additional $2 million of cash contributed by NRG to repay the cash grant bridge loan. The revolving facility can be used for cash or for the issuance of up to $9 million in letters of credit. As of December 31, 2014, $55 million of notes were outstanding and $8 million of letters of credit were outstanding under the revolving facility.  The notes amortize on predetermined schedules and are secured by all of the assets of TA High Desert.
Kansas South Facility
The Kansas South Facility includes a $38 million term loan due 2031 and a $21 million cash grant bridge loan due ten days after receipt of the cash grant. The term loan has an interest rate of 6 month LIBOR plus an applicable margin of 2.625% and increases by 0.25% every 4 years. The cash grant bridge loan had an interest rate of 1 month LIBOR plus an applicable margin of 2.00%. The term loan amortizes on a predetermined schedule and is secured by all of the assets of RE Kansas South. As described in Note 4,  Property, Plant and Equipment , in April 2014, the Company received payment of $21 million for the cash grant related to RE Kansas South and utilized the proceeds to repay the cash grant bridge loan. On September 26, 2014, RE Kansas South amended its credit agreement to change the interest rate to 6 month LIBOR plus 2.00% through September 30, 2019 and to 6 month LIBOR plus 2.250% thereafter. As of December 31, 2014, $35 million was outstanding under the term loan and $4 million of letters of credit were issued under the Kansas South Facility.
Avra Valley Credit Agreement
On July 9, 2014, Avra Valley amended its credit agreement to increase its borrowings by $3 million and to reduce the related interest rate from 3 month LIBOR plus an applicable margin of 2.25% to 3 month LIBOR plus 1.75%. The proceeds were primarily utilized to make a distribution to NRG Yield Operating LLC.

36

                                                

Alta Wind Financing Arrangements
As described in Note 3, Business Acquisitions, the Company acquired the Alta Wind Portfolio on August 12, 2014. In connection with the acquisition, the Company assumed the following debt arrangements:
Term Loan and Note Facilities
In June 2013, Alta Wind X entered into a credit agreement with several lenders for $337 million, which provided loans for the construction of the plant, letters of credit commitments to support certain obligations and a debt reserve loan commitment. The agreement contains a $300 million construction loan which converted to a term loan on March 31, 2014 and matures in March 2021. The term loan has an interest rate of 3 month LIBOR plus an applicable margin. The applicable margin was initially set at 2.00% for LIBOR-based loan increasing to 2.25% on the fourth anniversary of term loan conversion. The Company pays a commitment fee on the unused portion of all instruments of 0.75% quarterly in arrears on the last business day of March, June, September and December. The credit agreement also provides for a $20 million letter of credit facility to support obligations of the project, which expires on the term loan maturity date and a $17 million debt service loan commitments in the event the project is unable to meet its debt service obligations. As of December 31, 2014, $5 million of letters of credit were issued and no borrowings were made under the debt service loan commitments. In addition, a $3 million letter of credit to support a liquidity reserve requirement was issued under the Yield Credit Facility.
In June 2013, Alta Wind XI entered into a credit agreement with several lenders for $212 million, which provided loans for the construction of the plant, letters of credit commitments to support certain obligations and a debt reserve loan commitment. The agreement contains a $191 million construction loan which converted to a term loan on March 31, 2014 and matures in March 2021. The term loan has an interest rate of 3 month LIBOR plus an applicable margin. The applicable margin was initially set at 2.00% for LIBOR-based loan increasing to 2.25% on the fourth anniversary of term loan conversion. The Company pays a commitment fee on the unused portion of all instruments of 0.75% quarterly in arrears on the last business day of March, June, September and December. The credit agreement also provides for a $10 million letter of credit facility to support obligations under the PPA, which expires on the term loan maturity date and an $11 million in debt service loan commitments in the event the project is unable to meet its debt service obligations. As of December 31, 2014, no letters of credit were issued and no borrowings were made under the debt service loan commitments. In addition, a $3 million letter of credit to support a liquidity reserve requirement was issued under the Yield Credit Facility.
On May 22, 2013, AWAM entered into a credit agreement with a lender and borrowed a $20 million term loan. The proceeds from the issuance of the term loan were utilized to pay transactions costs and fund certain restricted cash accounts. AWAM has a $20 million term loan as of December 31, 2014, which has an interest rate of 3 month LIBOR plus an applicable margin of 2.375% and increases every four years to a maximum applicable margin of 2.88%. Principal and interest are payable quarterly on February 15, May 15, August 15 with a final maturity on May 15, 2031. The loan is secured by substantially all of the assets of AWAM. The term loan also has a debt service requirement, which is satisfied with a $1 million letter of credit issued under the Yield Credit Facility.
On January 31, 2011, Alta Realty entered into a $30 million note purchase agreement with a group of institutional investors with interest and principal payable quarterly on January 31, April 30, July 31, and October 31. The note has an interest rate of 7% and matures on January 31, 2031. The note purchase agreement also has a debt service requirement, which is satisfied with a $2 million letter of credit issued under the Yield Credit Facility. As of December 31, 2014, $34 million was outstanding under the note purchase agreement.
Lease financing arrangements
Alta Wind Holdings (Alta Wind II - V) and Alta I (operating entities) have finance lease obligations issued under lease transactions whereby the respective operating entities sold and leased back undivided interests in specific assets of the project. The sale and related lease transactions are accounted for as financing arrangements as the operating entities have continued involvement with the property. The terms and conditions of each facility lease are substantially similar. Each operating entity makes rental payments as stipulated in the facility lease agreements on a semiannual basis every June 30 and December 30 through the final maturity dates. In addition, the operating entities have a credit agreement with a group of lenders that provides for the issuance of letters of credit to support certain operating and debt service obligations. Certain O&M and rent reserve requirements are satisfied by letters of credit issued under the NRG Yield Operating agreement. As of December 31, 2014, $1,036 million was outstanding under the finance lease obligations, and $114 million of letters of credit issued under the credit agreement and $29 million issued under the Yield Credit Facility.

37

                                                

Laredo Ridge Credit Agreement
Prior to the acquisition of Laredo Ridge by NRG, Laredo Ridge LLC entered into a credit agreement with a group of lenders for a $75 million construction loan that was converted to a term loan upon completion of the project, a $53 million cash grant loan, which was repaid prior to the acquisition, and a $3 million working capital loan facility, all of which are secured by the assets of Laredo Ridge LLC. The credit agreement also included a letter of credit facility on behalf of Laredo Ridge LLC of up to $9 million, with a fee equal to the applicable margin on issued letters of credit. On December 17, 2014, Laredo Ridge LLC amended the credit agreement to increase its term loan borrowings by an additional $41 million, to reduce the working capital facility by $1 million, to increase the letter of credit facility by $1 million and to reduce the related interest rate to LIBOR plus 1.875% through December 31, 2018, LIBOR plus 2.125% from January 1, 2019 through December 31, 2023 and LIBOR plus 2.375% from January 1, 2024 through the maturity date. The fee on the working capital facility was reduced to 0.5%. In addition, the maturity date was extended to March 31, 2028. The proceeds were utilized to make a distribution of $33 million to NRG, with the remaining $8 million utilized to fund the costs of the amendment. As of December 31, 2014, $108 million was outstanding under the term loan, nothing was outstanding under the working capital facility, and $10 million of letters of credit in support of the project were issued.
Tapestry Wind Credit Agreement
Prior to the acquisition of the Tapestry projects by NRG, Tapestry Wind LLC entered into a credit agreement with a group of lenders for a $214 million term loan and an $8 million working capital loan facility. The term loan matures in December 2021 and is secured by Tapestry Wind LLC's interest in the Buffalo Bear, Taloga, and Pinnacle projects. The term loan amortizes based upon a predetermined schedule. The working capital facility is available to fund the operating needs of Tapestry Wind LLC with a commitment fee of 0.75%. The credit agreement also includes a letter of credit facility on behalf of Tapestry Wind LLC of up to $20 million, with a fee equal to the applicable margin on issued letters of credit.
On November 12, 2014, Tapestry Wind LLC amended the credit agreement to reduce the related interest rate to LIBOR plus 1.625% through December 20, 2018 and LIBOR plus 1.750% from December 21, 2018 through the maturity date. As of December 31, 2014, $192 million was outstanding under the term loan, nothing was outstanding under the working capital facility and $20 million of letters of credit in support of the project were issued.
Walnut Creek Credit Agreement
Prior to the acquisition of Walnut Creek by NRG, Walnut Creek Energy LLC entered into a credit agreement, or the Walnut Creek Agreement, with a group of lenders for a $442 million construction loan that was converted to a term loan upon completion of the project, and a $5 million working capital loan facility, which are secured by the assets of Walnut Creek Energy LLC. The term loan amortizes based upon a predetermined schedule and matures in May 2023. The working capital facility is available to fund the operating needs of Walnut Creek Energy LLC, with a commitment fee of 0.625%. The Walnut Creek Agreement also includes a letter of credit facility of up to $117 million, with a fee equal to the applicable margin on issued letters of credit. As of December 31, 2014, $391 million was outstanding under the term loan, nothing was outstanding under the working capital facility, and $41 million of letters of credit were issued.

On October 21, 2014, the Walnut Creek Agreement was amended to increase its term loan borrowings by an additional $10 million, and to reduce the related interest rate to LIBOR plus 1.625% through September 30, 2018, LIBOR plus 1.750% from October 1, 2018 through September 30, 2022, and LIBOR plus 1.875% from October 1, 2022, through the maturity date. The fee on the working capital facility was reduced to 0.5%. The proceeds were utilized to make a distribution of $6 million to WCEP Holdings LLC with the remaining $4 million utilized to fund the costs of the amendment. In addition, Walnut Creek entered into an additional interest rate swap to maintain the minimum of 90% of the outstanding notional amount being swapped to a fixed interest rate. Walnut Creek Energy LLC pays its counterparty the equivalent of a 4.0025% fixed interest payment on a predetermined notional value, and quarterly, Walnut Creek Energy LLC receives the equivalent of a floating interest payment based on a three-month LIBOR calculated on the same notional value through July 31, 2020. All interest rate swap payments are made quarterly and the LIBOR is determined in advance of each interest period.
WCEP Holdings LLC
Prior to the acquisition of Walnut Creek by NRG, WCEP Holdings LLC, the holding company of Walnut Creek Energy LLC, entered into a credit agreement with a group of lenders for a $53 million construction loan that was converted to a term loan upon completion of the Walnut Creek project. The term loan has an interest rate of LIBOR plus an applicable margin of 4.00%, amortizes based upon a predetermined schedule, matures in May 2023 and is secured by WCEP Holdings LLC's interest in the Walnut Creek project. As of December 31, 2014, $46 million was outstanding under the term loan.

38

                                                

On October 21, 2014, WCEP Holdings LLC amended the credit agreement to reduce the related interest rate to LIBOR plus 3.00%. The proceeds of the distribution from Walnut Creek Energy LLC were utilized to make an optional repayment of $6 million on the term loan. In addition, WCEP Holdings LLC partially terminated its interest rate swap agreements so that at least 90% and no more than 100% of the aggregate principal amount of the loans then outstanding would be subject to interest rate agreements.
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. In connection with the acquisition of the Alta Wind Portfolio, as described in Note 3,  Business Acquisitions , the Company acquired thirty-one additional interest rate swaps.

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, 2014.

 	 	% of Principal	 	Fixed Interest Rate	 	Floating Interest Rate	 	Notional Amount at December 31, 2014
(In millions)	 	Effective Date	 	Maturity Date	
NRG Marsh Landing LLC	 	75%	 	3.244%	 	3-Month LIBOR	 	$	431	
 	 	June 28, 2013	 	June 30, 2023	
NRG West Holdings LLC	 	75%	 	2.417%	 	3-Month LIBOR	 	384	
 	 	November 30, 2011	 	August 31, 2023	
South Trent Wind LLC	 	75%	 	3.265%	 	3-Month LIBOR	 	48	
 	 	June 15, 2010	 	June 14, 2020	
South Trent Wind LLC	 	75%	 	4.95%	 	3-Month LIBOR	 	21	
 	 	June 30, 2020	 	June 14, 2028	
NRG Solar Roadrunner LLC	 	75%	 	4.313%	 	3-Month LIBOR	 	31	
 	 	September 30, 2011	 	December 31, 2029	
NRG Solar Blythe LLC	 	75%	 	3.563%	 	3-Month LIBOR	 	17	
 	 	June 25, 2010	 	June 25, 2028	
NRG Solar Avra Valley LLC	 	85%	 	2.333%	 	3-Month LIBOR	 	54	
 	 	November 30, 2012	 	November 30, 2030	
NRG Solar Alpine LLC	 	85%	 	2.744%	 	3-Month LIBOR	 	129	
 	 	various	 	December 31, 2029	
NRG Solar Alpine LLC	 	85%	 	2.421%	 	3-Month LIBOR	 	10	
 	 	June 24, 2014	 	June 30, 2025	
Kansas South LLC	 	75%	 	2.368%	 	3-Month LIBOR	 	26	
 	 	June 28, 2013	 	December 31, 2030	
NRG Solar Borrego LLC	 	75%	 	1.125%	 	3-Month LIBOR	 	11	
 	 	April 3, 2013	 	June 30, 2020	
Alta X	 	100%	 	various	 	3-Month LIBOR	 	174	
 	 	December 31, 2013	 	December 31, 2015	
Alta X	 	100%	 	various	 	3-Month LIBOR	 	126	
 	 	December 31, 2013	 	December 31, 2025	
Alta X	 	100%	 	various	 	3-Month LIBOR	 	162	
 	 	December 31, 2015	 	December 31, 2020	
Alta X	 	100%	 	various	 	3-Month LIBOR	 	103	
 	 	December 31, 2020	 	December 31, 2025	
Alta XI	 	100%	 	various	 	3-Month LIBOR	 	138	
 	 	December 31, 2013	 	December 31, 2015	
Alta XI	 	100%	 	various	 	3-Month LIBOR	 	54	
 	 	December 31, 2013	 	December 31, 2025	
Alta XI	 	100%	 	various	 	3-Month LIBOR	 	103	
 	 	December 31, 2015	 	December 31, 2020	
Alta XI	 	100%	 	various	 	3-Month LIBOR	 	65	
 	 	December 31, 2020	 	December 31, 2025	
AWAM	 	100%	 	2.47%	 	3-Month LIBOR	 	20	
 	 	May 22, 2013	 	May 15, 2031	
Laredo Ridge	 	90%	 	2.31%	 	3-Month LIBOR	 	86	
 	 	March 31, 2011	 	March 31, 2026	
Tapestry	 	90%	 	2.21%	 	3-Month LIBOR	 	172	
 	 	December 30, 2011	 	December 21, 2021	
Tapestry	 	50%	 	3.57%	 	3-Month LIBOR	 	60	
 	 	December 21, 2021	 	December 21, 2029	
Walnut Creek Energy	 	90%	 	various	 	3-Month LIBOR	 	345	
 	 	June 28, 2013	 	May 31, 2023	
WCEP Holdings	 	90%	 	4.003%	 	3-Month LIBOR	 	47	
 	 	June 28, 2013	 	May 31, 2023	
Total	 	 	 	 	 	 	 	$	2,817	

39

                                                

Annual Maturities
Annual payments based on the maturities of the Company's debt, for the years ending after December 31, 2014, are as follows:

 	(In millions)	
2015	$	214	
 	
2016	246	
 	
2017	259	
 	
2018	264	
 	
2019	625	
 	
Thereafter	3,198	
 	
Total	$	4,806	
 	
Note 10 — Earnings Per Share 
Basic and diluted earnings per common share are computed by dividing net income by the weighted average number of common shares outstanding. Shares issued during the year are weighted for the portion of the year that they were outstanding.
The reconciliation of the Company's basic and diluted earnings per share is shown in the following table, after giving effect to the stock split as described in Note 1,  Nature of Business :

 	Class A Common Stock	 	Class C Common Stock	
 	Year ended December 31, 2014	 	Period from July 23, 2013 to December 31, 2013	 	Year ended December 31, 2014	 	Period from July 23, 2013 to December 31, 2013	
(In millions, except per share data)	 	 	 	 	 	 	 	
Basic and diluted earnings per share attributable to NRG Yield, Inc. common stockholders	 	 	 	 	 	 	 	
Net income attributable to NRG Yield, Inc.	$	8	
 	 	$	7	
 	 	$	8	
 	 	$	7	
 	
Weighted average number of common shares outstanding	28	
 	 	23	
 	 	28	
 	 	23	
 	
Earnings per weighted average common share — basic and diluted	$	0.30	
 	 	$	0.29	
 	 	$	0.30	
 	 	$	0.29	
 	
There were a total of six million anti-dilutive outstanding equity instruments related to the Convertible Notes for the year ended December 31, 2014 with respect to the calculation of diluted earnings per share for the Company's Class A common stock and a total of six million anti-dilutive outstanding equity instruments related to the Convertible Notes for the year ended December 31, 2014 with respect to the calculation of diluted earnings per share for the Company's Class C common stock.
Note 11 — Stockholders' Equity
On July 22, 2013, in connection with its initial public offering, the Company authorized 500,000,000 shares of Class A common stock, par value $0.01 per share, of which 22,511,250 were issued to the public in connection with the initial public offering and became outstanding. In return for the issuance of these shares, the Company received $468 million, net of underwriting discounts and commissions of $27 million. In addition, in connection with the initial public offering, the Company authorized 500,000,000 shares of Class B common stock, par value $0.01 per share, of which 42,738,750 were issued to NRG concurrently with the initial public offering and became outstanding. The Company utilized $395 million of the proceeds from the issuance of the Class A common stock to acquire a controlling interest in NRG Yield LLC from NRG. Each share of both of the Class A common stock and Class B common stock entitles the holder to one vote on all matters. Class A common stockholders hold 100% of the economic interest and a 34.5% voting interest in the Company. Class B common stockholders held a 65.5% voting interest in NRG, Yield, Inc. prior to the secondary offering
On July 29, 2014, the Company issued 12,075,000 shares of Class A common stock for net proceeds, after underwriting discount and expenses, of $630 million. The Company utilized the proceeds of the offering to acquire 12,075,000 additional Class A units of NRG Yield LLC and, as a result, as of December 31, 2014, the Company owns 44.7% of NRG Yield LLC, and consolidates the results of NRG Yield LLC through its controlling interest, with NRG's 55.3% interest shown as noncontrolling interest in the financial statements.

40

                                                

Recapitalization    
On May 5, 2015, the Company's stockholders approved amendments to the Company's certificate of incorporation that resulted in the creation of two new classes of capital stock, Class C common stock and Class D common stock. The recapitalization became effective on May 14, 2015, with the split of each outstanding share of Class A common stock into one share of Class A common stock and one share of Class C common stock, and the split of each outstanding share of Class B common stock into one share of Class B common stock and one share of Class D common stock.
The Class C common stock and Class D common stock have the same rights and privileges and rank equally, share ratably and are identical in all respects to the shares of Class A common stock and Class B common stock, respectively, as to all matters, except that each share of Class C common stock and Class D common stock is entitled to 1/100th of a vote on all stockholder matters. The par value per share of the Company’s Class A common stock and Class B common stock remains unchanged at $0.01 per share after the effect of the stock split described above. Accordingly, the stock split is accounted for as a stock dividend. The Company recorded a transfer between retained earnings and common stock equal to the par value of each share of Class C common stock and Class D common stock that is issued. The Company also gave retrospective effect to prior period share and per share amounts in the audited historical consolidated financial statements for the effect of the stock dividend, such that all periods are comparable.
Dividends to Class A and Class C common stockholders
The following table lists the dividends paid on the Company's Class A common stock during the year ended December 31, 2014:

 	Fourth Quarter 2014	 	Third Quarter 2014	 	Second Quarter 2014	 	First Quarter 2014	
Dividends per share	$	0.375	
 	 	$	0.365	
 	 	$	0.35	
 	 	$	0.33	
 	
On February 17, 2015, the Company declared a quarterly dividend on its Class A common stock of $0.39 per share payable on March 16, 2015, to stockholders of record as of March 2, 2015.
On May 20, 2015, the Company declared a quarterly dividend on its Class A common stock and Class C common stock of $0.20 per share payable on June 15, 2015, to holders of Class A common stock and Class C common stock of record as of June 1, 2015.
Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations.
The Company also authorized 10,000,000 shares of preferred stock, par value $0.01 per share. None of the shares of preferred stock have been issued.
Distributions to NRG
The following table lists the distributions paid to NRG during the year ended December 31, 2014:

 	Fourth Quarter 2014	 	Third Quarter 2014	 	Second Quarter 2014	 	First Quarter 2014	
Distributions per unit	$	0.375	
 	 	$	0.365	
 	 	$	0.35	
 	 	$	0.33	
 	
The portion of the distributions paid by NRG Yield LLC to NRG was recorded as a reduction to the Company's noncontrolling interest balance. The portion of the distributions paid by NRG Yield LLC to the Company was utilized to fund the dividends to the Class A common stockholders described above.
On February 17, 2015, the Company declared a quarterly distribution on its Class B units of $0.39 per unit payable on March 16, 2015.
On June 30, 2014, the Company acquired the TA High Desert, RE Kansas South, and El Segundo projects, as discussed in Note 3,  Business Acquisitions . The difference between the cash paid and historical value of the entities' equity of $113 million was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. In addition, as the TA High Desert, RE Kansas South and El Segundo projects were owned by NRG until June 30, 2014, the pre-acquisition earnings of such projects are recorded as attributable to NRG's noncontrolling interest. Prior to the date of acquisition, El Segundo made a distribution to NRG of $23 million. Additionally, NRG Repowering Holding LLC (a wholly owned subsidiary of NRG) paid a contribution of $2 million to TA High Desert.

41

                                                

On January 2, 2015, the Company acquired Laredo Ridge, Walnut Creek, and Tapestry projects, as discussed in Note 3, Business Acquisitions . The difference between the cash paid and historical value of the entities' equity of $61 million, as well as $23 million of AOCL, was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest. In addition, as Laredo Ridge, Walnut Creek and Tapestry projects were owned by NRG until January 2, 2015, the pre-acquisition earnings of such projects are recorded as attributable to NRG's noncontrolling interest. Prior to the date of acquisition, Laredo Ridge, Walnut Creek and Tapestry projects made distributions to NRG, net of contributions, of $41 million.

42

                                                

Note 12 — Segment Reporting 
The Company’s segment structure reflects how management currently makes financial decisions and allocates resources. Its businesses are primarily segregated based on conventional power generation, renewable businesses which consist of solar and wind, and the thermal and chilled water business. The Corporate segment reflects the Company's corporate costs.
The Company generated more than 10% of its revenues from the following customers for the years ended December 31, 2014, and 2013. For the year ended December 31, 2012, there were no customers from whom the Company derived more than 10% of consolidated revenue.

 	2014	 	2013	
Customer	Conventional (%)	 	Renewables (%)	 	Conventional (%)	 	Renewables (%)	
Southern California Edison	28%	 	9%	 	15%	 	4%	
Pacific Gas and Electric	18%	 	4%	 	22%	 	7%	

 	

 	Year ended December 31, 2014	
(In millions)	Conventional Generation	
 	Renewables	
 	Thermal	
 	Corporate	
 	Total	
Operating revenues	$	317	
 	
 	$	177	
 	
 	$	195	
 	
 	$	—	
 	
 	$	689	
 	
Cost of operations	55	
 	
 	45	
 	
 	139	
 	
 	—	
 	
 	239	
 	
Depreciation and amortization	82	
 	
 	66	
 	
 	18	
 	
 	—	
 	
 	166	
 	
General and administrative — affiliate	—	
 	
 	—	
 	
 	—	
 	
 	8	
 	
 	8	
 	
Acquisition-related transaction and integration costs	—	
 	 	—	
 	 	—	
 	 	4	
 	 	4	
 	
Operating income (loss)	180	
 	 	66	
 	 	38	
 	 	(12	)	 	272	
 	
Equity in earnings of unconsolidated affiliates	14	
 	
 	13	
 	
 	—	
 	
 	—	
 	
 	27	
 	
Other income, net	—	
 	 	2	
 	 	—	
 	 	1	
 	 	3	
 	
Interest expense	(53	)	
 	(96	)	
 	(7	)	
 	(30	)	
 	(186	)	
Income (loss) before income taxes	141	
 	
 	(15	)	
 	31	
 	
 	(41	)	
 	116	
 	
Income tax expense	—	
 	
 	—	
 	
 	—	
 	
 	4	
 	
 	4	
 	
Net Income (Loss)	$	141	
 	
 	$	(15	)	
 	$	31	
 	
 	$	(45	)	
 	$	112	
 	
Balance Sheet	

 	

 	

 	

 	

Equity investment in affiliates	$	114	
 	
 	$	113	
 	
 	$	—	
 	
 	$	—	
 	
 	$	227	
 	
Capital expenditures(a)	6	
 	
 	(1	)	
 	7	
 	
 	—	
 	
 	12	
 	
Total Assets	$	2,194	
 	
 	$	3,856	
 	
 	$	437	
 	
 	$	478	
 	
 	$	6,965	
 	
(a) Includes accruals. Capital expenditures for Renewables include a sales tax refund received by Alpine in the first quarter of 2014.

 	Year ended December 31, 2013	
(In millions)	Conventional Generation	 	Renewables	 	Thermal	 	Corporate	 	Total	
Operating revenues	$	138	
 	 	$	89	
 	 	$	152	
 	 	$	—	
 	 	$	379	
 	
Cost of operations	23	
 	 	11	
 	 	110	
 	 	—	
 	 	144	
 	
Depreciation and amortization	20	
 	 	26	
 	 	15	
 	 	—	
 	 	61	
 	
General and administrative — affiliate	—	
 	 	—	
 	 	—	
 	 	7	
 	 	7	
 	
Operating income (loss)	95	
 	 	52	
 	 	27	
 	 	(7	)	 	167	
 	
Equity in earnings of unconsolidated affiliates	16	
 	 	6	
 	 	—	
 	 	—	
 	 	22	
 	
Other income, net	1	
 	 	2	
 	 	—	
 	 	—	
 	 	3	
 	
Interest expense	(25	)	 	(20	)	 	(7	)	 	—	
 	 	(52	)	
Income (loss) before income taxes	87	
 	 	40	
 	 	20	
 	 	(7	)	 	140	
 	
Income tax expense	—	
 	 	—	
 	 	—	
 	 	8	
 	 	8	
 	
Net Income (Loss)	$	87	
 	 	$	40	
 	 	$	20	
 	 	$	(15	)	 	$	132	
 	
Balance Sheet	 	 	 	 	 	 	 	 	 	
Equity investments in affiliates	$	118	
 	 	$	109	
 	 	$	—	
 	 	$	—	
 	 	$	227	
 	
Capital expenditures (a)	168	
 	 	30	
 	 	15	
 	 	—	
 	 	213	
 	
Total Assets	$	1,584	
 	 	$	1,046	
 	 	$	436	
 	 	$	172	
 	 	$	3,238	
 	
(a) Includes accruals.

43

                                                

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Year ended December 31, 2012	
(In millions)	Conventional Generation	 	Renewables	 	Thermal	 	Corporate	 	Total	
Operating revenues	$	—	
 	 	$	33	
 	 	$	142	
 	 	$	—	
 	 	$	175	
 	
Cost of operations	2	
 	 	9	
 	 	103	
 	 	—	
 	 	114	
 	
Depreciation and amortization	—	
 	 	10	
 	 	15	
 	 	—	
 	 	25	
 	
General and administrative — affiliate	—	
 	 	—	
 	 	—	
 	 	7	
 	 	7	
 	
Operating income (loss)	(2	)	 	14	
 	 	24	
 	 	(7	)	 	29	
 	
Equity in earnings of unconsolidated affiliates	15	
 	 	4	
 	 	—	
 	 	—	
 	 	19	
 	
Other income, net	1	
 	 	1	
 	 	—	
 	 	—	
 	 	2	
 	
Interest expense	—	
 	 	(20	)	 	(8	)	 	—	
 	 	(28	)	
Income (loss) before income taxes	14	
 	 	(1	)	 	16	
 	 	(7	)	 	22	
 	
Income tax expense	—	
 	 	—	
 	 	—	
 	 	10	
 	 	10	
 	
Net Income (Loss)	$	14	
 	 	$	(1	)	 	$	16	
 	 	$	(17	)	 	$	12	

Note 13 — Income Taxes 
Effective Tax Rate
The income tax provision from continuing operations consisted of the following amounts:

 	Year Ended December 31,	
 	2014	 	2013	 	2012	
 	(In millions, except percentages)	
Current	 	 	 	 	 	
U.S. Federal	$	—	
 	 	$	—	
 	 	$	7	
 	
Total — current	—	
 	 	—	
 	 	7	
 	
Deferred	 	 	 	 	 	
U.S. Federal	2	
 	 	14	
 	 	1	
 	
State	2	
 	 	(6	)	 	2	
 	
Total — deferred	4	
 	 	8	
 	 	3	
 	
Total income tax expense	$	4	
 	 	$	8	
 	 	$	10	
 	
Effective tax rate	3.4	%	 	5.7	%	 	45.7	%	
A reconciliation of the U.S. federal statutory rate of 35% to the Company's effective rate is as follows:

 	Year Ended December 31,	
 	2014	 	2013 (a)	 	2012 (b)	
 	(In millions, except percentages)	
Income Before Income Taxes	116	
 	 	140	
 	 	22	
 	
Tax at 35%	41	
 	 	49	
 	 	8	
 	
State taxes, net of federal benefit	1	
 	 	(6	)	 	2	
 	
Impact of non-taxable equity earnings	(33	)	 	(35	)	 	—	
 	
Production tax credits	(6	)	 	—	
 	 	—	
 	
Change in state effective tax rate	1	
 	 	—	
 	 	—	
 	
Income tax expense	$	4	
 	 	$	8	
 	 	$	10	
 	
Effective income tax rate	3.4	%	 	5.7	%	 	45.7	%	
(a)  - Represents 34.5% ownership for the period July 22, 2013 through December 31, 2013
(b) - Represents pro forma tax provision for NRG Yield LLC
For the year ended December 31, 2014, the overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its 55.3% interest in NRG Yield LLC and production tax credits generated from certain Alta Wind Portfolio facilities.
For the year ended December 31, 2013, the overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its 65.5% interest in NRG Yield LLC.

44

                                                

On July 22, 2013, the Company acquired a controlling interest in NRG Yield LLC and its subsidiary NRG Yield Operating LLC. On July 29, 2014, the Company issued additional shares of Class A common stock, and as a result, it currently owns 44.7% of NRG Yield LLC and consolidates the results due to its controlling interest. The Company records NRG's 55.3% ownership as noncontrolling interest in the financial statements. For tax purposes, NRG Yield LLC is treated as a partnership; therefore, the Company and NRG each record their respective share of taxable income or loss.
The temporary differences, which gave rise to the Company's deferred tax assets, consisted of the following:

 	As of December 31,	
 	2014	 	2013	
 	(In millions)	
Deferred tax assets:	 	 	 	
Investment in projects	$	47	
 	 	$	81	
 	
Production tax credits carryforwards	6	
 	 	—	
 	
U.S. Federal net operating loss carryforwards	74	
 	 	61	
 	
State net operating loss carryforwards	7	
 	 	4	
 	
Total deferred tax assets	134	
 	 	146	
 	
Net deferred tax asset	$	134	
 	 	$	146	
 	
The following table summarizes the Company's net deferred tax position:

 	As of December 31,	
 	2014	 	2013	
 	(In millions)	
Net deferred tax asset — current	$	16	
 	 	$	—	
 	
Net deferred tax asset — noncurrent	118	
 	 	146	
 	
Net deferred tax asset	$	134	
 	 	$	146	
 	
Tax Receivable and Payable
As of December 31, 2014, the Company had a domestic tax receivable of $6 million which related to federal cash grants for Borrego project. This amount is fully reserved pending further discussions with the US Treasury Department.
Deferred Tax Assets and Valuation Allowance
Net deferred tax balance — As of December 31, 2014, and 2013, NRG recorded a net deferred tax asset of $134 million and $146 million, respectively. The Company believes it is more likely than not that the results of future operations will generate sufficient taxable income which includes the future reversal of existing taxable temporary differences to realize deferred tax assets. In arriving at this conclusion to utilize projections of future profit before tax in its estimate of future taxable income, the Company considered the profit before tax generated in recent years.
NOL carryforwards — At December 31, 2014, the Company had domestic NOLs consisting of carryforwards for federal income tax purposes of $74 million and cumulative state NOLs of $7 million tax-effected.
Uncertain Tax Positions
The Company had no identified uncertain tax positions that require evaluation as of December 31, 2014.

45

                                                

Note 14 — Related Party Transactions 
Management Services Agreement by and between NRG and the Company
Since the Company has no employees, NRG provides the Company with various operation, management, and administrative services, which include human resources, accounting, tax, legal, information systems, treasury, and risk management, as set forth in the Management Services Agreement. As of December 31, 2014, the base management fee was approximately $6 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, 2014, the fee was increased by approximately $2 million per year in connection with the acquisition of the Acquired ROFO Assets and Alta Wind Portfolio. Costs incurred under this agreement were approximately $8 million for the year ended December 31, 2014 and $3 million for the period beginning July 23, 2013 and ending December 31, 2013. These costs included certain direct expenses incurred by NRG on behalf of the Company in addition to the base management fee, $5 million of which was unpaid as of December 31, 2014 and bears no interest. The balance was classified as a liability under accounts payable — affiliate in the Company's consolidated balance sheets as of December 31, 2014, and repaid in February 2015.
Operation and Maintenance Services (O&M) Agreements by and between NRG and Thermal Entities
On October 1, 2014, NRG entered into Plant O&M Services Agreements with certain wholly-owned subsidiaries of the Company. NRG provides necessary and appropriate services to operate and maintain the subsidiaries' plant operations, businesses and thermal facilities. NRG is to be reimbursed for the provided services, as well as for all reasonable and related expenses and expenditures, and payments to third parties for services and materials rendered to or on behalf of the parties to the agreements. NRG is not entitled to any management fee or mark-up under the agreements. Prior to October 1, 2014, NRG provided same services to Thermal entities on an informal basis. For the years ended December 31, 2014 and 2013, total fees incurred under the agreements were $27 million and $24 million, respectively. There was a balance of $22 million due to NRG in accounts payable — affiliate as of December 31, 2014.
O&MServices Agreements by and between NRG and GenConn
GenConn incurs fees under two O&M agreements with wholly-owned subsidiaries of NRG. The fees incurred under the agreements were $6 million, $5 million and $5 million for the years ended December 31, 2014, 2013 and 2012, respectively.
Power Sales and Services Agreement by and between NRG and NRG Energy Center Dover LLC
NRG Energy Center Dover LLC, or NRG Dover, a subsidiary of the Company is party to a Power Sales and Services Agreement with NRG Power Marketing LLC, or NRG Power Marketing, a wholly-owned subsidiary of NRG. The agreement is automatically renewed on a month-to-month basis unless terminated by either party upon at least 30 day written notice. Under the agreement, NRG Power Marketing has the exclusive right to (i) manage, market and sell power, (ii) procure fuel and fuel transportation for operation of the Dover generating facility, to include for purposes other than generating power, (iii) procure transmission services required for the sale of power, and (iv) procure and market emissions credits for operation of the Dover generating facility.
In addition, NRG Power Marketing has the exclusive right and obligation to direct the output from the generating facility, in accordance with and to meet the terms of any power sales contracts executed against the power generation of the Dover facility. Under the agreement, NRG Power Marketing pays NRG Dover gross receipts generated through sales, less costs incurred by NRG Power Marketing related to providing such services as transmission and delivery costs, as well as fuel costs. During 2011, the existing coal purchase contract expired and NRG Power Marketing entered into a new contract, which expired in December 2012, to purchase coal for the Dover Facility. For the year ended December 31, 2012, NRG Dover purchased approximately $2 million under this agreement. In July 2013, the originally coal-fueled plant was converted to a natural gas facility. For the years ended December 31, 2014, and 2013, NRG Dover purchased approximately $10 million and $5 million, respectively, of natural gas from NRG Power Marketing.

46

                                                

O&MServices Agreements by and between El Segundo and NRG El Segundo Operations
El Segundo incurs fees under an O&M agreement with NRG El Segundo Operations, Inc., a wholly-owned subsidiary of NRG. Under the O&M agreement, NRG El Segundo Operations, Inc. manages, operates and maintains the El Segundo facility for an initial term of ten years following the commercial operations date. For the years ended December 31, 2014, 2013, and 2012, the costs incurred under the agreement were approximately $4 million, $5 million, and $1 million, respectively. For the years ended December 31, 2013 and 2012, $2 million and $1 million of the costs incurred were capitalized and recorded to property, plant and equipment in the Company's consolidated balance sheets.

Ground Lease and Easement Agreement by and between El Segundo and El Segundo Power, LLC
El Segundo incurred lease expense under a ground lease and easement agreement with El Segundo Power, LLC, a wholly-owned subsidiary of NRG, for a parcel of real property in the city of El Segundo, California. The nonexclusive easements are for the support infrastructure for the project. The initial term of the agreement was over the construction of the project through the twentieth anniversary of the commercial operations date. For the years ended December 31, 2014, 2013, and 2012, the Company incurred costs of approximately $1 million for each year. The costs are included in cost of operations in the Company's consolidated statements of operations.
Construction Management Services Agreement by and between El Segundo and NRG Construction Services LLC
El Segundo incurred fees under a construction management services agreement with NRG Construction Services LLC, a wholly-owned subsidiary of NRG, to act as construction manager of the project to manage the design, engineering, procurement and construction, commissioning, testing initial start-up and closeout of construction activities for the facility. For the years ended December 31, 2013 and 2012, total costs incurred were $4 million and $4 million, respectively. The costs were capitalized and recorded to property, plant and equipment in the Company's consolidated balance sheets. El Segundo achieved commercial operations in August 2013.
Energy Marketing Services Agreement with NRG Power Marketing LLC
El Segundo was a party to an energy marketing services agreement with NRG Power Marketing LLC, a wholly-owned subsidiary of NRG, to procure fuel and market capacity, energy and ancillary output of the facility prior to the start of the PPA with Southern California Edison. The agreement began in April 2013 and ended at the commercial operations date in August 2013. For the years ended December 31, 2014 and 2013, the Company recorded approximately $1 million and $12 million, respectively, in costs related to this agreement of which $9 million was recorded to property, plant and equipment in 2013, with remaining amount recorded to cost of operations in the Company's statement of operations.
Administrative Services Agreement by and between Marsh Landing and GenOn Energy Services, LLC
Marsh Landing is a party to an administrative services agreement with GenOn Energy Services, LLC, a wholly owned subsidiary of NRG, which provides with processing and paying invoices services on behalf of Marsh Landing. Marsh Landing reimburses GenOn Energy Services, LLC for the amounts paid by it. The Company reimbursed costs under this agreement of approximately $13 million, $36 million, and $2 million for the years ended December 31, 2014, 2013 and 2012, respectively. For the years ended December 31, 2014, 2013 and 2012, $2 million, $29 million and $2 million, respectively, were capitalized. There was a balance of $4 million and $2 million due to GenOn Energy Services, LLC in accounts payable - affiliate as of December 31, 2014 and 2013, respectively.

47

                                                

Accounts Payable to NRG Renew LLC
During the third quarter of 2013, NRG Renew LLC (formerly known as NRG Solar LLC), a wholly-owned subsidiary of NRG, made 100% of the required capital contributions to CVSR, including the Company's 48.95% portion, of which $14 million was outstanding as of December 31, 2013. This balance was repaid to NRG Renew LLC during the quarter ended March 31, 2014.
Accounts Payable to NRG Repowering Holdings LLC
During 2013, NRG Repowering Holdings, LLC, a wholly-owned subsidiary of NRG, made payments to BA Leasing BSC, LLC, or BA Leasing, of $18 million, which were expected to be repaid with the proceeds of the cash grant received by BA leasing with respect to the PFMG DG Solar Projects, in connection with a sale-leaseback arrangement between the PFMG DG Solar Projects and BA Leasing. As of December 31, 2013, PFMG DG Solar Projects had a corresponding receivable for the reimbursement of the cash grant from BA Leasing and related payable to NRG Repowering Holdings, LLC. In the first quarter of 2014, the PFMG DG Solar Projects received $11 million from BA Leasing and reduced the remaining receivable with an offset to the deferred liability recorded in connection with the sale - leaseback arrangement. The PFMG DG Solar Projects utilized the $11 million to repay NRG Repowering Holdings LLC.

Note 15 — 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 $5 million for the year ended December 31, 2014, and $2 million for each of the years ended 2013 and 2012.
Future minimum lease commitments under operating leases for the years ending after December 31, 2014, are as follows:

Period	(In millions)	
2015	$	12	
 	
2016	11	
 	
2017	7	
 	
2018	7	
 	
2019	7	
 	
Thereafter	133	
 	
Total	$	177	
 	
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, 2014, 2013 and 2012, the Company purchased $55 million, $40 million, and $30 million, respectively, under such arrangements.
As of December 31, 2014, the Company's commitments under such outstanding agreements are estimated as follows:

Period	(In millions)	
2015	$	15	
 	
2016	4	
 	
2017	3	
 	
2018	3	
 	
2019	2	
 	
Thereafter	26	
 	
Total	$	53	
 	
Contingencies

48

                                                

In the normal course of business, the Company is subject to various claims and litigation. Management expects that these various litigation items will not have a material adverse effect on the Company's results of operations or financial position.
Note 16 — Environmental Matters

In 2013, NRG Energy Center San Francisco LLC, a wholly owned indirect subsidiary of the Company, received a notice of violation from the San Francisco Department of Public Health alleging improper monitoring of three underground storage tanks. The tanks have not leaked. The Company settled the matter in July 2014 for $123,000.

49

                                                

Note 17 — 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. Summarized unaudited quarterly financial data is as follows:

 	Quarter Ended	
 	December 31, (a)	 	September 30, (a)	 	June 30, (a)	 	March 31, (c)	
 	2014	
(As recast)	(In millions, except per share data)	
Operating Revenues	$	192	
 	 	$	184	
 	 	$	173	
 	 	$	140	
 	
(As previously reported in 2014 Form 10-K)	 	 	 	 	 	 	 	
Operating Revenues	148	
 	 	161	
 	 	134	
 	 	140	

(Change )	44	
 	 	23	
 	 	39	
 	 	—	

(As recast)	 	 	 	 	 	 	 	
Operating Income	70	
 	 	84	
 	 	64	
 	 	54	
 	
(As previously reported in 2014 Form 10-K)	 	 	 	 	 	 	 	
Operating Income	46	
 	 	70	
 	 	51	
 	 	54	

Change	24	
 	 	14	
 	 	13	
 	 	—	

(As recast)	 	 	 	 	 	 	 	
Net Income	5	
 	 	40	
 	 	41	
 	 	26	
 	
(As previously reported in 2014 Form 10-K)	 	 	 	 	 	 	 	
Net (Loss) Income	$	(10	)	 	$	31	
 	 	$	34	
 	 	$	26	

(Change)	15	
 	 	9	
 	 	7	
 	 	—	

Net Income Attributable to NRG Yield, Inc.	$	—	
 	 	$	6	
 	 	$	6	
 	 	$	4	
 	
Weighted average number of Class A common shares outstanding - basic and diluted  (b)	35	
 	 	31	
 	 	23	
 	 	23	
 	
Earnings per Weighted Average Class A Common Share - Basic and Diluted  (b)	$	0.01	
 	 	$	0.10	
 	 	$	0.13	
 	 	$	0.09	
 	
Weighted average number of Class C common shares outstanding - basic and diluted  (b)	35	
 	 	31	
 	 	23	
 	 	23	
 	
Earnings per Weighted Average Class C Common Share - Basic and Diluted  (b)	$	0.01	
 	 	$	0.10	
 	 	$	0.13	
 	 	$	0.09	

 	

(a) The Company's unaudited quarterly financial data was recast for the effect of the EME-NYLD-Eligible Assets, from the date the entities were under common control or April 1, 2014.
(b) Adjusted to give effect to the stock split, as described in Note 1, Nature of Business.
(c)  The Acquired ROFO Assets were purchased on June 30, 2014, and accordingly the Company had previously reported operating revenues of $110 million, operating income of $38 million and net income of $18 million for the three months ended March 31, 2014.

50

                                                

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Quarter Ended	
 	December 31, (c)	 	September 30, (a) (c)	 	June 30, (c)	 	March 31, (c)	
 	2013	
(As recast)	(In millions, except per share data)	
Operating Revenues	$	118	
 	 	$	126	
 	 	$	82	
 	 	$	53	
 	
(As previously reported in 2013 Form 10-K)	 	 	 	 	 	 	 	
Operating Revenues	86	
 	 	95	
 	 	79	
 	 	53	

(Change )	32	
 	 	31	
 	 	3	
 	 	—	

(As recast)	 	 	 	 	 	 	 	
Operating Income	54	
 	 	63	
 	 	38	
 	 	12	
 	
(As previously reported in 2013 Form 10-K)	 	 	 	 	 	 	 	
Operating Income	33	
 	 	45	
 	 	38	
 	 	12	

(Change )	21	
 	 	18	
 	 	—	
 	 	—	

(As recast)	 	 	 	 	 	 	 	
Net Income	37	
 	 	49	
 	 	35	
 	 	11	
 	
(As previously reported in 2013 Form 10-K)	 	 	 	 	 	 	 	
Net Income	$	24	
 	 	40	
 	 	$	34	
 	 	$	11	

(Change )	13	
 	 	9	
 	 	1	
 	 	—	

Net Income Attributable to NRG Yield, Inc.	$	4	
 	 	$	9	
 	 	n/a	
 	 	n/a	
 	
Weighted average number of Class A common shares outstanding - basic and diluted	23	
 	 	23	
 	 	n/a	
 	 	n/a	
 	
Weighted average number of Class C common shares outstanding - basic and diluted	23	
 	 	23	
 	 	n/a	
 	 	n/a	
 	
Earnings per Weighted Average Class A Common Share - Basic and Diluted  (b)	$	0.09	
 	 	$	0.20	
 	 	n/a	
 	 	n/a	
 	
Earnings per Weighted Average Class C Common Share - Basic and Diluted  (b)	$	0.09	
 	 	$	0.20	
 	 	n/a	
 	 	n/a	

 	

(a) Earnings per weighted average class A and Class C common share are calculated for the period of July 22, 2013 to September 30, 2013.
(b) Adjusted to give effect to the stock split, as described in Note 1, Nature of Business.
(c) The Company's unaudited quarterly financial data was recast for the effect of the Acquired ROFO Assets.

51

                                                

Schedule I
NRG Yield, Inc. (Parent)
Condensed Financial Information of Registrant
Condensed Statements of Income

 	 	 	 	 	 	 	 	
 	Year ended December 31,	
(In millions)	2014 (a)	 	2013 (a)	
 	 	 	 	
Equity earnings in consolidated subsidiaries	$	121	
 	 	$	86	
 	
Interest expense	(5	)	 	—	
 	
Income Before Income Taxes	116	
 	 	86	
 	
Income tax expense	4	
 	 	8	
 	
Net Income	112	
 	 	78	
 	
Less: Pre-acquisition net income of Drop Down Assets	48	
 	 	23	
 	
Less: Net income attributable to NRG	48	
 	 	42	
 	
Net Income Attributable to NRG Yield, Inc.	$	16	
 	 	$	13	

 	

(a) Retrospectively adjusted as discussed in Note 1, Nature of Business of the Company's consolidated financial statements.

See accompanying notes to condensed financial statements.

52

                                                

Schedule I
NRG Yield, Inc.
Condensed Balance Sheets

 	Year ended December 31,	
 	2014 (a)	 	2013 (a)	
 	(In millions)	
Assets	 	 	 	
Current Assets:	 	 	 	
Deferred income taxes	16	
 	 	—	
 	
Noncurrent Assets:	 	 	 	
Investment in consolidated subsidiaries	1,735	
 	 	1,106	
 	
Note receivable - Yield Operating	337	
 	 	—	
 	
Debt Issuance Costs	5	
 	 	—	
 	
Deferred income taxes	118	
 	 	146	
 	
Total Assets	$	2,211	
 	 	$	1,252	

Liabilities and Equity	 	 	 	
 	 	 	 	
Deferred income taxes	—	
 	 	—	
 	
Long-term debt	326	
 	 	—	
 	
Total Liabilities	326	
 	 	—	

Stockholders' Equity:	 	 	 	
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued	—	
 	 	—	
 	
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 154,650,000 (Class A 34,586,250, Class B 42,738,750, Class C 34,586,250, Class D 42,738,750) and 130,500,540 (Class A 22,511,520, Class B 42,738,750, Class C 22,511,520, Class D 42,738,750) shares issued and outstanding at December 31, 2014 and 2013	—	
 	 	—	
 	
Additional paid-in capital	1,240	
 	 	621	
 	
Retained earnings	3	
 	 	8	
 	
Accumulated other comprehensive loss	(9	)	 	—	
 	
Noncontrolling interest	651	
 	 	623	
 	
Total Stockholders' Equity	1,885	
 	 	1,252	
 	
Total Liabilities and Stockholders' Equity	$	2,211	
 	 	$	1,252	

 	

(a) Retrospectively adjusted as discussed in Note 1, Nature of Business of the Company's consolidated financial statements.

See accompanying notes to condensed financial statements.

53

                                                

Schedule I
NRG Yield, Inc.
Condensed Statements of Cash Flows

 	 	 	 	 	 	 	 	
 	Years ended December 31,	
 	2014 (a)	 	2013 (a)	
 	(In millions)	
Net Cash (Used in) Provided by Operating Activities	$	(1	)	 	$	5	
 	
Cash Flows from Investing Activities	 	 	 	
Investments in consolidated affiliates	(630	)	 	(468	)	
Increase in notes receivable - affiliate	(337	)	 	—	
 	
Net Cash Used in Investing Activities	(967	)	
 	(468	)	
Cash Flows from Financing Activities	 	 	 	
Proceeds from issuance of debt	345	
 	 	—	
 	
Proceeds from issuance of Class A common shares	630	
 	 	468	
 	
Payment of debt issuance costs	(7	)	 	—	
 	
Cash received from Yield LLC for the payment of dividends	41	
 	 	—	
 	
Payment of dividends to Class A common shareholders	(41	)	 	(5	)	
Net Cash Provided by Financing Activities	968	
 	 	463	
 	
Net Change in Cash and Cash Equivalents	—	
 	 	—	
 	
Cash and Cash Equivalents at Beginning of Period	—	
 	 	—	
 	
Cash and Cash Equivalents at End of Period	$	—	
 	 	$	—	

 	

(a) Retrospectively adjusted as discussed in Note 1, Nature of Business of the Company's consolidated financial statements.

See accompanying notes to condensed financial statements.

54

                                                

Schedule I
NRG Yield, Inc. (Parent)
Notes to Condensed Financial Statements

Note 1 — Background and Basis of Presentation
Background
    
NRG Yield, Inc., or the Company, is a dividend growth-oriented company formed on December 20, 2012. The Company used the net proceeds from its initial public offering of Class A common stock on July 22, 2013 to acquire 100%, or 22,511,250, of the Class A units of NRG Yield LLC. In connection with the acquisition of the Class A units, the Company also became the sole managing member of NRG Yield LLC, thereby acquiring a controlling interest. NRG Yield LLC, through its wholly owned subsidiary, NRG Yield Operating LLC, is a holder of a portfolio of contracted renewable and conventional generation and thermal infrastructure assets, primarily located in the Northeast, Southwest and California regions of the U.S.
Prior to the secondary offering, the Company and NRG owned 34.5% and 65.5% of NRG Yield LLC, respectively. On July 29, 2014, the Company issued 12,075,000 shares of Class A common stock in a secondary offering for net proceeds, after underwriting discount and expenses, of $630 million. The Company utilized the proceeds of the offering to acquire 12,075,000 additional Class A units of NRG Yield LLC and, as a result, subsequent to the secondary offering and as of December 31, 2014, the Company owns 44.7% of NRG Yield LLC, and consolidates the results of NRG Yield LLC through its controlling interest, with NRG's 55.3% interest shown as noncontrolling interest in the financial statements. The holders of the Company's issued and outstanding shares of Class A common stock an entitled to 100% of the Company's economic interests and are entitled to dividends. NRG receives distributions from Yield LLC through its ownership of Class B common units.
On May 5, 2015, the Company's stockholders approved amendments to the Company's certificate of incorporation that resulted in the creation of two new classes of capital stock, Class C common stock and Class D common stock. The recapitalization became effective on May 14, 2015, with the split of each outstanding share of Class A common stock into one share of Class A common stock and one share of Class C common stock, and the split of each outstanding share of Class B common stock into one share of Class B common stock and one share of Class D common stock.
The Class C common stock and Class D common stock have the same rights and privileges and rank equally, share ratably and are identical in all respects to the shares of Class A common stock and Class B common stock, respectively, as to all matters, except that each share of Class C common stock and Class D common stock is entitled to 1/100th of a vote on all stockholder matters. The par value per share of the Company’s Class A common stock and Class B common stock remains unchanged at $0.01 per share after the effect of the stock split described above. Accordingly, the stock split is accounted for as a stock dividend. The Company recorded a transfer between retained earnings and common stock equal to the par value of each share of Class C common stock and Class D common stock that is issued. The Company also gave retrospective effect to prior period share and per share amounts in the audited historical consolidated financial statements for the effect of the stock dividend, such that all periods are comparable. As such, the Company's historical financial statements previously filed with the SEC have been recast in this Current Report on Form 8-K to include the retrospective effect of the stock split on all the periods reported.

Basis of Presentation
The condensed parent-only company financial statements have been prepared in accordance with Rule 12-04 of
Regulation S-X, as the restricted net assets of NRG Yield, Inc.’s subsidiaries exceed 25% of the consolidated net assets of
NRG Yield, Inc. The parent's 100% investment in its subsidiaries has been recorded using the equity basis of accounting in the accompanying condensed parent-only financial statements. These statements should be read in conjunction with the consolidated statements and notes thereto of NRG Yield, Inc.

As described in Note 1, Nature of Business, the Company's consolidated financial statements, the Company's historical financial statements for and as of the year ended December 31, 2014 previously filed with the SEC have been recast in this Current Report on Form 8-K to include the results attributable to the EME-NYLD-Eligible Assets from the date these entities were under common control, or April 1, 2014.

Note 2 — Long-Term Debt
For a discussion of NRG Yield Inc.’s financing arrangements, see Note 9, Debt and Capital Leases, to the Company's consolidated financial statements.

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Note 3 — Commitments, Contingencies and Guarantees
See Note 13, Income Taxes and Note 15, Commitments and Contingencies to the Company's consolidated financial statements for a detailed discussion of NRG Yield, Inc.’s commitments and contingencies.

Note 4 — Dividends
Cash distributions paid to NRG Yield, Inc. by its subsidiary, NRG Yield LLC, were $41 million and $5 million for the years ended December 31, 2014 and 2013, respectively.

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