Document

 
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 _____________________________________________________________________________
FORM 10-K
 _____________________________________________________________________________
(Mark One)
x
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year ended December 31, 2017
OR
o
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from              to             
Commission File Number: 001-36542
 ______________________________________________________________
https://cdn.kscope.io/f4c1aef99ef6528fa659800937cdf5ef-image2017.jpg
TerraForm Power, Inc.
(Exact name of registrant as specified in its charter)
 _____________________________________________________________________________
Delaware
 
46-4780940
(State or other jurisdiction of incorporation or organization)
 
(I. R. S. Employer Identification No.)
7550 Wisconsin Avenue, 9th Floor, Bethesda, Maryland
 
20814
(Address of principal executive offices)
 
(Zip Code)
240-762-7700
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class
 
Name of Exchange on Which Registered
Common Stock, Class A, par value $0.01
 
NASDAQ Global Select Market
Securities registered pursuant to Section 12(g) of the Act: None
___________________________________________________________
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined by Rule 405 of the Securities Act.  Yes  o    No  x
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  Yes  o    No  x
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes  x    No  o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  Yes  x    No  o
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of the registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.   o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.



Large accelerated filer
 
x
 
Accelerated filer
 
o
Non-accelerated filer
 
o (Do not check if a smaller reporting company)
 
Smaller reporting company
 
o
Emerging growth company
 
o
 
 
 
 
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes  o    No  x
As of June 30, 2017, the last business day of the registrant's most recently completed second fiscal quarter, the aggregate market value of the voting and non-voting common equity of the registrant, held by non-affiliates of the registrant (based upon the closing sale price of shares of Class A common stock of the registrant on the NASDAQ Global Select Market on such date), was approximately $1.1 billion.
As of February 28, 2018, there were 148,086,027 shares of Class A common stock outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant's definitive proxy statement relating to its 2018 annual meeting of stockholders (the “2018 Proxy Statement”) are incorporated by reference into Part III of this Form 10-K where indicated. The 2018 Proxy Statement will be filed with the U.S. Securities and Exchange Commission within 120 days after the end of the fiscal year to which this report relates.
 



TerraForm Power, Inc. and Subsidiaries
Table of Contents
Form 10-K
 
 
 
 
 
 
 
 
 
 
Item 1.
Item 1A.
Item 1B.
Item 2.
Item 3.
Item 4.
 
 
 
 
 
 
 
Item 5.
Item 6.
Item 7.
Item 7A.
Item 8.
Item 9.
Item 9A.
Item 9B.
 
 
 
 
 
 
 
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
 
 
 
 
Item 15.




CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS
This communication contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements can be identified by the fact that they do not relate strictly to historical or current facts. These statements involve estimates, expectations, projections, goals, assumptions, known and unknown risks, and uncertainties and typically include words or variations of words such as “expect,” “anticipate,” “believe,” “intend,” “plan,” “seek,” “estimate,” “predict,” “project,” “goal,” “guidance,” “outlook,” “objective,” “forecast,” “target,” “potential,” “continue,” “would,” “will,” “should,” “could,” or “may” or other comparable terms and phrases. All statements that address operating performance, events, or developments that the Company expects or anticipates will occur in the future are forward-looking statements. They may include estimates of expected cash available for distribution, earnings, revenues, capital expenditures, liquidity, capital structure, future growth, financing arrangements and other financial performance items (including future dividends per share), descriptions of management’s plans or objectives for future operations, products, or services, or descriptions of assumptions underlying any of the above. Forward-looking statements provide the Company’s current expectations or predictions of future conditions, events, or results and speak only as of the date they are made. Although the Company believes its expectations and assumptions are reasonable, it can give no assurance that these expectations and assumptions will prove to have been correct and actual results may vary materially.

Important factors that could cause actual results to differ materially from our expectations, or cautionary statements, are listed below and further disclosed under the section entitled Item 1A. Risk Factors:

risks related to the transition to Brookfield Asset Management Inc. sponsorship, including our ability to realize the expected benefits of the sponsorship;
risks related to wind conditions at our wind assets or to weather conditions at our solar assets;
risks related to the effectiveness of our internal controls over financial reporting;
pending and future litigation;
the willingness and ability of counterparties to fulfill their obligations under offtake agreements;
price fluctuations, termination provisions and buyout provisions in offtake agreements;
our ability to enter into contracts to sell power on acceptable prices and terms, including as our offtake agreements expire;
our ability to compete against traditional and renewable energy companies;
government regulation, including compliance with regulatory and permit requirements and changes in tax laws, market rules, rates, tariffs, environmental laws and policies affecting renewable energy;
risks related to the proposed relocation of the Company’s headquarters;
the condition of the debt and equity capital markets and our ability to borrow additional funds and access capital markets, as well as our substantial indebtedness and the possibility that we may incur additional indebtedness going forward;
operating and financial restrictions placed on us and our subsidiaries related to agreements governing indebtedness;
risks related to the expected timing and likelihood of completion of the tender offer for the shares of Saeta Yield, S.A., including the timing or receipt of any governmental approvals;
risks related to our financing of the tender offer for the shares of Saeta Yield, S.A., including our ability to issue equity on terms that are accretive to our shareholders and our ability to implement our permanent funding plan;
our ability to successfully identify, evaluate and consummate acquisitions; and
our ability to integrate the projects we acquire from third parties, including Saeta Yield, S.A., or otherwise and realize the anticipated benefits from such acquisitions.

The Company disclaims any obligation to publicly update or revise any forward-looking statement to reflect changes in underlying assumptions, factors, or expectations, new information, data, or methods, future events, or other changes, except as required by law. The foregoing list of factors that might cause results to differ materially from those contemplated in the forward-looking statements should be considered in connection with information regarding risks and uncertainties, which are described in this Annual Report on Form 10-K, as well as additional factors we may describe from time to time in other filings with the SEC. We operate in a competitive and rapidly changing environment. New risks and uncertainties emerge from time to time, and you should understand that it is not possible to predict or identify all such factors and, consequently, you should not consider any such list to be a complete set of all potential risks or uncertainties.



GLOSSARY OF TERMS

When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below:
Adjusted EBITDA
 
Adjusted EBITDA is defined as net income (loss) plus depreciation, accretion and amortization, non-cash general and administrative costs, interest expense, income tax (benefit) expense, acquisition related expenses, and certain other non-cash charges, unusual or non-recurring items and other items that we believe are not representative of our core business or future operating performance.
Cash available for distribution
 
Cash available for distribution is defined as adjusted EBITDA (i) minus cash distributions paid to non-controlling interests in our renewable energy facilities, if any, (ii) minus annualized scheduled interest and project-level amortization payments in accordance with the related borrowing arrangements, (iii) minus average annual sustaining capital expenditures (based on the long-sustaining capital expenditure plans) which are recurring in nature and used to maintain the reliability and efficiency of our power generating assets over our long-term investment horizon, (iv) plus or minus operating items as necessary to present the cash flows we deem representative of our core business operations. For items determined on an annualized basis, we used actual cash payments as a proxy for an annualized number prior to the period commencing January 1, 2018.
GWh
 
Gigawatt hours
ITC
 
Investment tax credit
MW
 
Megawatt
MWh
 
Megawatt hours
Nameplate capacity
 
Nameplate capacity for solar generation facilities represents the maximum generating capacity at standard test conditions of a facility (in direct current, “DC”) multiplied by our percentage ownership of that facility (disregarding any equity interests held by any non-controlling member or lessor under any sale-leaseback financing or any non-controlling interests in a partnership). Nameplate capacity for wind power plants represents the manufacturer’s maximum nameplate generating capacity of each turbine (in alternating current, “AC”) multiplied by the number of turbines at a facility multiplied by our percentage ownership of that facility (disregarding any equity interests held by any tax equity investor or lessor under any sale-leaseback financing or any non-controlling interests in a partnership).
PPA
 
As applicable, Power Purchase Agreement, energy hedge contract and/or REC or SREC contract
PTC
 
Production tax credit
REC
 
Renewable energy certificate or SREC
Renewable energy facilities
 
Solar generation facilities and wind power plants
SREC
 
Solar renewable energy certificate




PART I

Item 1. Business.

Overview

TerraForm Power, Inc. (“TerraForm Power”) owns and operates a high-quality, diversified portfolio of solar and wind assets located primarily in the United States and underpinned by long-term contracts, totaling more than 2,600 MW of installed capacity. TerraForm Power’s goal is to acquire operating solar and wind assets in North America and Western Europe and it is sponsored by Brookfield Asset Management Inc. (“Brookfield”), a leading global alternative asset manager with more than $265 billion of assets under management.

TerraForm Power's objective is to deliver an attractive risk-adjusted return to its shareholders. We expect to generate this total return with a regular dividend, which we intend to grow at 5 to 8% per annum, that is backed by stable cash flows.

TerraForm Power is a holding company and its only material asset is an equity interest in TerraForm Power, LLC, or “Terra LLC.” TerraForm Power is the managing member of Terra LLC and operates, controls and consolidates the business affairs of Terra LLC. Unless otherwise indicated or otherwise required by the context, references to “we,” “our,” “us” or the “Company” refer to TerraForm Power and its consolidated subsidiaries.

Our principal executive offices are located at 7550 Wisconsin Avenue, 9th Floor, Bethesda, Maryland 20814, and our telephone number is (240) 762-7700. Our website address is www.terraformpower.com. Information contained on our website is not incorporated by reference into this Annual Report on Form 10-K and does not constitute part of this Annual Report on Form 10-K.


6




The diagram below is a summary depiction of our organizational and capital structure as of December 31, 2017:
https://cdn.kscope.io/f4c1aef99ef6528fa659800937cdf5ef-orgchart2017.jpg
—————
(1)
As of December 31, 2017, there were 148,086,027 Class A shares of TerraForm Power outstanding, of which Orion US Holdings 1 L.P. (“Orion Holdings”) owns 51%. In turn, Orion Holdings is managed and controlled by Brookfield.
(2)
Incentive distribution rights (“IDRs”) represent a variable interest in distributions by Terra LLC and therefore cannot be expressed as a fixed percentage ownership interest in Terra LLC. BRE Delaware, Inc. (the “Brookfield IDR Holder”) holds all of the IDRs of Terra LLC. Brookfield IDR Holder is an indirect wholly owned subsidiary of Brookfield.
(3)
See Liquidity and Capital Resources within Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations for discussion regarding these financing arrangements.
(4)
Terra LLC is a guarantor of the indebtedness of Terra Operating LLC.
(5)
Represents total borrowing capacity as of December 31, 2017. As of December 31, 2017, there were $60.0 million of revolving loans and $102.6 million of letters of credit outstanding under the New Revolver, with availability of $287.4 million as of such date.
(6)
Certain project-level holding companies are guarantors of the indebtedness of Terra Operating LLC. These specific project-level holding companies do not have any indebtedness.



7


Our Business Strategy

Our primary business strategy is to acquire, own and operate solar and wind assets in North America and Western Europe. We are the owner and operator of a 2,600 MW diversified portfolio of high-quality solar and wind assets, located primarily in the United States and underpinned by long-term contracts. Significant diversity across technologies and locations coupled with contracts across a large, diverse group of creditworthy counterparties significantly reduces the impact of resource variability on cash available for distribution and limits our exposure to any individual counterparty.

On April 21, 2016, SunEdison, Inc. (together with its consolidated subsidiaries excluding the Company and TerraForm Global, Inc. and its subsidiaries, “SunEdison”), our previous sponsor, and certain of its domestic and international subsidiaries (the “SunEdison Debtors”) voluntarily filed for protection under Chapter 11 of the U.S. Bankruptcy Code (the “SunEdison Bankruptcy”). In response to SunEdison’s financial and operating difficulties, we initiated a process for the exploration and evaluation of potential strategic alternatives for the Company. This process resulted in our entry into a definitive merger and sponsorship transaction agreement (the “Merger Agreement”) on March 6, 2017 with Orion Holdings and BRE TERP Holdings Inc. (“Merger Sub”), a wholly-owned subsidiary of Orion Holdings, which are both affiliates of Brookfield. At the same time, we also entered into a settlement agreement (the “Settlement Agreement”) and a voting and support agreement (the “Voting and Support Agreement”) with SunEdison to, among other things, facilitate the closing of the merger transaction and the settlement of claims between the Company and SunEdison.

On October 16, 2017, Merger Sub merged with and into TerraForm Power (the “Merger”), with TerraForm Power continuing as the surviving corporation in the Merger, and the Company entered into a suite of support and sponsorship arrangements (the “Sponsorship Transaction”) with Brookfield and certain of its affiliates, as described in greater detail below. In this Annual Report on Form 10-K, we generally refer to these collective transactions, and any other agreements or arrangements entered into in connection therewith, as the “Merger and Sponsorship Transaction.”

In connection with the successful completion of the Merger and Sponsorship Transaction, Brookfield replaced SunEdison as our sponsor and all outstanding claims between us and SunEdison that may have existed prior to the closing of the Merger and Sponsorship Transaction were finally settled, and all agreements between the Company and the SunEdison Debtors were deemed rejected, subject to certain limited exceptions, without further liability, claims or damages on the part of the Company.

Our goal is to pay dividends to our shareholders that are sustainable on a long-term basis while retaining within our operations sufficient liquidity for recurring growth capital expenditures and general purposes. We expect to generate this return with a regular dividend, which we intend to grow at 5 to 8% per annum, that is supported by a target payout ratio of 80 to 85% of cash available for distribution and our stable cash flows. We expect to achieve this growth and deliver returns by focusing on the following initiatives:

Margin Enhancements:
We believe there is significant opportunity to enhance our cash flow through productivity enhancements by rationalizing our headcount and implementing a more efficient organizational structure. In addition, we plan to automate a number of processes that are currently very labor intensive and expect to realize cost savings through reductions in operations and maintenance (“O&M”) expenses and the in-sourcing of asset management and certain back office functions.

Organic Growth:
We plan to develop a robust organic growth pipeline comprised of opportunities to invest in our existing fleet on an accretive basis as well as add-on acquisitions across our scope of operations. We have identified a number of opportunities which we believe may be compelling to invest in our fleet, including asset repowerings, site expansions and potentially adding energy storage to existing sites.

Value-oriented acquisitions:
We expect to evaluate a number of acquisition opportunities with a focus on sourcing off-market transactions at more attractive valuations than auction processes. Our recently announced tender offer for the outstanding shares of Saeta Yield, S.A. (as described below under Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield) is an example of these acquisition opportunities. We believe that multi-faceted transactions such as take-privates and recapitalizations may enable us to acquire high quality assets at attractive relative values.


8


We have a right of first offer (“ROFO”) to acquire certain renewable power assets in North America and Western Europe owned by Brookfield and its affiliates. The ROFO portfolio currently stands at 3,500 MW. Over time, as Brookfield entities look to sell these assets, we will have the opportunity to make offers for these assets and potentially purchase them if the prices meet our investment objectives and are the most favorable offered to Brookfield. We also continue to maintain a call right over 0.5 GW (net) of operating wind power plants that are owned by a warehouse vehicle that was owned and arranged by SunEdison. SunEdison sold its equity interest in this warehouse vehicle to an unaffiliated third party in 2017.
    
We believe we are well positioned to benefit from Brookfield's deep operational expertise in owning, operating and developing renewable assets, as well as its significant deal sourcing capabilities and access to capital. Brookfield is a leading global alternative asset manager and has a more than 100-year history of owning and operating assets with a focus on renewable power, property, infrastructure and private equity. Brookfield has approximately $40 billion in renewable power assets under management, representing approximately 16,400 MW of generation capacity in 14 countries. It also employs over 2,000 individuals with extensive operating, development and power marketing capabilities and has a demonstrated ability to deploy capital in a disciplined manner, having developed or acquired 12,000 MW of renewable generation capacity since 2012.
    
Sponsorship Arrangements

On October 16, 2017, in connection with the consummation of the Merger, TerraForm Power entered into the following:
Master Services Agreement (the “Brookfield MSA”), with Brookfield, BRP Energy Group L.P., Brookfield Asset Management Private Institutional Capital Adviser (Canada), L.P., Brookfield Global Renewable Energy Advisor Limited, Terra LLC and Terra Operating LLC, pursuant to which Brookfield and certain of its affiliates will provide certain management and administrative services, including the provision of strategic and investment management services, to TerraForm Power and its subsidiaries.
Relationship Agreement (the “Relationship Agreement”) with Brookfield, Terra LLC and Terra Operating LLC, which governs certain aspects of the relationship between Brookfield and TerraForm Power and its subsidiaries. Pursuant to the Relationship Agreement, during the term of the agreement, TerraForm Power and its subsidiaries serve as the primary vehicle through which Brookfield and its affiliates will acquire operating solar and wind assets in certain countries in North America and Western Europe, and Brookfield grants TerraForm Power a right of first offer on any proposed transfer of certain existing projects and all future operating solar and wind projects located in such countries developed by persons sponsored by or under the control of Brookfield.
Governance Agreement (the “Governance Agreement”) with Orion Holdings and any controlled affiliate of Brookfield (other than TerraForm Power and its controlled affiliates) (together with Brookfield, the “Sponsor Group”) that by the terms of the Governance Agreement from time to time becomes a party thereto. The Governance Agreement establishes certain rights and obligations of TerraForm Power and members of the Sponsor Group that own voting securities of TerraForm Power relating to the governance of TerraForm Power and the relationship between such members of the Sponsor Group and TerraForm Power and its controlled affiliates.

We also entered into an amended and restated limited liability company agreement with Brookfield IDR Holder and a $500.0 million sponsor line of credit with Brookfield and one of its affiliates as discussed in Liquidity and Capital Resources within Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.        

Recent Corporate Governance and Management Changes

Certain corporate governance changes were implemented following the completion of the Merger and Sponsorship Transaction. As part of the Merger and Sponsorship Transaction, TerraForm Power’s corporate governance was simplified to better align the interests of all of our stakeholders. We now have a single class of A shares worth one vote each, as opposed to our previous dual-class structure. Upon consummation of the Merger and Sponsorship Transaction, the size of our Board of Directors (the “Board”) was set at seven members, of whom four are designated by Brookfield and three are independent and were initially chosen by our Board prior to the Merger and Sponsorship Transaction. On November 16, 2017, one of our three independent directors resigned as a director, and as a result, a new independent director was appointed to our Board on February 5, 2018.

In addition, we have experienced changes to our executive officers and senior management, including the departure of our interim Chief Executive Officer, Chief Financial Officer and General Counsel upon the closing of the Merger and Sponsorship Transaction. The governance agreements entered into between the Company and Brookfield in connection with the


9


Merger and Sponsorship Transaction provide for Brookfield to appoint our Chief Executive Officer, Chief Financial Officer and General Counsel. These three executive officers are not employees of the Company and their services are provided pursuant to the Brookfield MSA.

Our Board has established an Audit Committee and a Conflicts Committee, consisting of our independent directors. The Conflicts Committee will consider, among other things, matters in which a conflict of interest exists between our company and Brookfield. Our Board has also established a Nominating and Governance Committee, which consists of three directors, one of whom is a director designated by Brookfield and two of whom are independent directors. See Item 10. Directors, Executive Officers and Corporate Governance for further discussion regarding our executive officers, directors and corporate governance.

Changes within Our Portfolio

The following table provides an overview of the changes within our portfolio from December 31, 2016 through December 31, 2017:
 
 
 
 
Net Nameplate Capacity (MW)¹
 
 
 
 
Facility Type
 
 
 Number of Sites
Description
 
 
Total Portfolio as of December 31, 2016
 
 
 
2,983.1

 
2,503

Sale of U.K. Utility Solar Portfolio
 
Solar
 
(208.4
)
 
(14
)
Sale of Fairwinds & Crundale
 
Solar
 
(55.9
)
 
(2
)
Sale of Stonehenge Q1
 
Solar
 
(41.2
)
 
(3
)
Sale of Stonehenge Operating
 
Solar
 
(23.6
)
 
(3
)
Sale of Says Court
 
Solar
 
(19.8
)
 
(1
)
Sale of Crucis Farm
 
Solar
 
(16.1
)
 
(1
)
Sale of Resi 2015 Portfolio 1
 
Solar
 
(8.9
)
 
(1,246
)
Sale of Resi 2014 Portfolio 1
 
Solar
 
(2.8
)
 
(700
)
Total Portfolio as of December 31, 2017
 
 
 
2,606.4

 
533

——————
(1)
Net nameplate capacity represents the maximum generating capacity at standard test conditions of a facility multiplied by the Company's percentage of economic ownership of that facility after taking into account any redeemable preference shares and stockholder loans the Company holds. Our percentage of economic ownership is subject to change in future periods for certain facilities.




























10


Our Portfolio

Our current portfolio consists of renewable energy facilities located in the United States (including Puerto Rico), Canada, Chile and the United Kingdom with a combined nameplate capacity of 2,606.4 MW as of December 31, 2017. These renewable energy facilities generally have long-term PPAs with creditworthy counterparties. As of December 31, 2017, on a weighted average basis (based on MW), our PPAs had a remaining life of 14 years and our counterparties to our PPAs had an investment grade credit rating.

The following table lists the renewable energy facilities that comprise our portfolio as of December 31, 2017:
Facility Category / Portfolio
 
Location
 
Nameplate Capacity (MW)
 
Net Nameplate Capacity (MW)
 
Number of Sites
 
Weighted Average Remaining Duration of PPA (Years)1
Solar Distributed Generation:
 
 
 
 
 
 
 
CD DG Portfolio
 
U.S.2
 
77.8

 
77.8

 
42

 
15

DG 2015 Portfolio 2
 
U.S.2
 
48.1

 
48.1

 
30

 
18

U.S. Projects 2014
 
U.S.2
 
45.4

 
45.4

 
41

 
17

DG 2014 Portfolio 1
 
U.S.2
 
44.0

 
44.0

 
46

 
17

TEG
 
U.S.2
 
33.8

 
32.0

 
56

 
12

HES
 
U.S.2
 
25.2

 
25.2

 
67

 
12

MA Solar
 
Massachusetts
 
21.1

 
21.1

 
4

 
24

Summit Solar Projects
 
U.S.2
 
19.6

 
19.6

 
50

 
10

U.S. Projects 2009-2013
 
U.S.2
 
15.2

 
15.2

 
73

 
12

SUNE XVIII
 
U.S.2
 
16.1

 
16.1

 
21

 
19

California Public Institutions
 
California
 
13.5

 
7.0

 
5

 
16

Enfinity
 
U.S.2
 
13.2

 
13.2

 
15

 
14

MA Operating
 
Massachusetts
 
12.2

 
12.2

 
4

 
16

Duke Operating
 
North Carolina
 
10.0

 
10.0

 
3

 
13

SunE Solar Fund X
 
U.S.2
 
8.8

 
8.8

 
12

 
13

Summit Solar Projects
 
Ontario
 
3.8

 
3.8

 
7

 
14

MPI
 
Ontario
 
4.7

 
4.7

 
13

 
16

Total Solar Distributed Generation
 
412.5

 
404.2

 
489

 
16

 
 
 
 
 
 
 
 
 
 
 
Solar Utility:
 
 
 
 
 
 
 
 
 
 
Mt. Signal
 
California
 
265.8

 
265.8

 
1

 
21

Regulus Solar
 
California
 
81.6

 
81.6

 
1

 
17

Blackhawk Solar Portfolio
 
U.S.2
 
72.8

 
72.8

 
10

 
20

North Carolina Portfolio
 
North Carolina
 
26.4

 
26.4

 
4

 
12

Atwell Island
 
California
 
23.5

 
23.5

 
1

 
20

Nellis
 
Nevada
 
14.0

 
14.0

 
1

 
10

Alamosa
 
Colorado
 
8.2

 
8.2

 
1

 
10

CalRENEW-1
 
California
 
6.3

 
6.3

 
1

 
12

Northern Lights
 
Ontario
 
25.4

 
25.4

 
2

 
16

Marsh Hill
 
Ontario
 
18.5

 
18.5

 
1

 
17

SunE Perpetual Lindsay
 
Ontario
 
15.5

 
15.5

 
1

 
17

Norrington
 
U.K.
 
11.1

 
11.1

 
1

 
11

CAP
 
Chile
 
101.6

 
101.6

 
1

 
16

Total Solar Utility
 
 
 
670.7

 
670.7

 
26

 
18

 
 
 
 
 
 
 
 
 
 
 


11


Facility Category / Portfolio
 
Location
 
Nameplate Capacity (MW)
 
Net Nameplate Capacity (MW)
 
Number of Sites
 
Weighted Average Remaining Duration of PPA (Years)1
Wind Utility:
 
 
 
 
 
 
 
 
 
 
South Plains I
 
Texas
 
200.0

 
200.0

 
1

 
10

California Ridge
 
Illinois
 
217.1

 
195.6

 
1

 
15

Bishop Hill
 
Illinois
 
211.4

 
190.5

 
1

 
15

Rattlesnake
 
Texas
 
207.2

 
186.7

 
1

 
10

Prairie Breeze
 
Nebraska
 
200.6

 
180.7

 
1

 
21

Cohocton
 
New York
 
125.0

 
125.0

 
1

 
2

Stetson I & II
 
Maine
 
82.5

 
82.5

 
2

 
2

Rollins
 
Maine
 
60.0

 
60.0

 
1

 
14

Mars Hill
 
Maine
 
42.0

 
42.0

 
1

 
2

Sheffield
 
Vermont
 
40.0

 
40.0

 
1

 
10

Bull Hill
 
Maine
 
34.5

 
34.5

 
1

 
9

Kaheawa Wind Power I
 
Hawaii
 
30.0

 
30.0

 
1

 
8

Kahuku
 
Hawaii
 
30.0

 
30.0

 
1

 
13

Kaheawa Wind Power II
 
Hawaii
 
21.0

 
21.0

 
1

 
15

Steel Winds I & II
 
New York
 
35.0

 
35.0

 
2

 
2

Raleigh
 
Ontario
 
78.0

 
78.0

 
1

 
13

Total Wind Utility
 
 
 
1,614.3

 
1,531.5

 
18

 
11

 
 
 
 
 
 
 
 
 
 
 
Total Renewable Energy Facilities
 
2,697.5

 
2,606.4

 
533

 
14

———
(1)
Calculated as of December 31, 2017.
(2)
These portfolios consist of renewable energy facilities located in multiple locations within the U.S., as follows:
CD DG Portfolio: California, Massachusetts, New Jersey, New York and Pennsylvania
DG 2015 Portfolio 2: Arizona, California, Connecticut, Massachusetts, New Jersey, Utah and Vermont
U.S. Projects 2014: Arizona, California, Connecticut, Georgia, Massachusetts, New Jersey, New York and Puerto Rico
DG 2014 Portfolio 1: Arizona, California, Georgia, Hawaii, Massachusetts, Maryland, New Jersey, New York, Oregon, Texas, Vermont and Puerto Rico
TEG: Arizona, California, Connecticut, Massachusetts, New Jersey and Pennsylvania
HES: Massachusetts, New Jersey and Pennsylvania
Summit Solar Projects (U.S.): California, Connecticut, Florida, Maryland and New Jersey
U.S. Projects 2009-2013: California, Colorado, Connecticut, Massachusetts, New Jersey, Oregon and Puerto Rico
SUNE XVIII: Arizona, California, Hawaii, Massachusetts, Maryland, Minnesota, New Hampshire, New York and Texas
Enfinity: Arizona, California and Ohio
SunE Solar Fund X: California, Maryland and New Mexico
Blackhawk Solar Portfolio: Utah, Florida, Nevada and California

Seasonality and Resource Availability

The amount of electricity produced and revenues generated by our solar generation facilities is dependent in part on the amount of sunlight, or irradiation, where the assets are located. As shorter daylight hours in winter months result in less irradiation, the electricity generated by these facilities will vary depending on the season. Irradiation can also be variable at a particular location from period to period due to weather or other meteorological patterns, which can affect operating results. As the great majority of our solar power plants are located in the Northern hemisphere, our solar portfolio’s power generation will be at its lowest during the first and fourth quarters of each year. Therefore, we expect our first and fourth quarter solar revenue generation to be lower than other quarters.



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Similarly, the electricity produced and revenues generated by our wind power plants depend heavily on wind conditions, which are variable and difficult to predict. Operating results for wind power plants vary significantly from period to period depending on the wind conditions during the periods in question. As our wind power plants are located in geographies with different profiles, there is some flattening of the seasonal variability associated with each individual wind power plant’s generation, and we expect that as the fleet expands the effect of such wind resource variability may be favorably impacted, although we cannot guarantee that we will purchase wind power facilities that will achieve such results in part or at all. Historically, our wind production is greater in the first and fourth quarters which can partially offset the lower solar revenue expected to be generated in those quarters.

We do not expect seasonality to have a material effect on our ability to pay a regular dividend. We intend to mitigate the effects of any seasonality that we experience by reserving a portion of our cash available for distribution and otherwise maintain sufficient liquidity, including cash on hand in order to, among other things, facilitate the payment of dividends to our stockholders.

Competition

Power generation is a capital-intensive business with numerous industry participants. We compete to acquire new renewable energy facilities with renewable energy developers who retain renewable energy asset ownership, independent power producers, financial investors and certain utilities. We compete to supply energy to our potential customers with utilities and other providers of distributed generation. We compete with other renewable energy developers, independent power producers and financial investors based on our cost of capital, development expertise, pipeline, global footprint and brand reputation. To the extent we re-contract renewable energy facilities upon termination of a PPA or sell electricity into the merchant power market, we compete with traditional utilities and other independent power producers primarily based on low cost of capital, generation located at customer sites, operations and management expertise, price (including predictability of price), green attributes (such as RECs and tax incentives) of renewable power and the ease by which customers can switch to electricity generated by our renewable energy facilities. In our merchant power sales, we also compete with other types of generation resources, including gas and coal-fired power plants.

Environmental Matters

We are subject to environmental laws and regulations in the jurisdictions in which we own and operate renewable energy facilities. These laws and regulations generally require that governmental permits and approvals be obtained and maintained both before construction and during operation of these renewable energy facilities. We incur costs in the ordinary course of business to comply with these laws, regulations and permit requirements. We do not anticipate material capital expenditures for environmental compliance for our renewable energy facilities in the next several years. While we do not expect that the costs of compliance would generally have a material impact on our business, financial condition or results of operations, it is possible that as the size of our portfolio grows we may become subject to new or modified regulatory regimes that may impose unanticipated requirements on our business as a whole that were not anticipated with respect to any individual renewable energy facility. Additionally, environmental laws and regulations frequently change and often become more stringent, or subject to more stringent interpretation or enforcement, and therefore future changes could require us to incur materially higher costs which could have a material negative impact on our financial performance or results of operations.

Regulatory Matters

All of the renewable energy facilities located in the United States that we own are qualifying small power production facilities (“QFs”) as defined under the Public Utilities Regulatory Policies Act of 1978, as amended (“PURPA”) or Exempt Wholesale Generators (“EWGs”). As a result, they and their upstream owners are exempt from the books and records access provisions of the Public Utilities Holding Company Act of 2005, as amended (“PUHCA”), and most are exempt from state organizational and financial regulation of electric utilities. Depending upon the power production capacity of the renewable energy facility in question, our QFs and their immediate project company owners may be entitled to various exemptions from ratemaking and certain other regulatory provisions of the Federal Power Act, as amended (“FPA”).

All of the renewable energy facility companies that we own outside of the United States are Foreign Utility Companies, as defined in PUHCA. They are exempt from state organizational and financial regulation of electric utilities and from most provisions of PUHCA and FPA.

We own a number of renewable energy facilities in the United States that are subject to the jurisdiction of the Federal Energy Regulatory Commission (“FERC”), and that have obtained “market based rate authorization” and associated blanket authorizations and waivers from FERC pursuant to the FPA, which allows it to sell electricity, capacity and ancillary services at


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wholesale or negotiated market based rates, instead of cost-of-service rates, as well as waivers of, and blanket authorizations under, certain FERC regulations that are commonly granted to market based rate sellers. FERC requires market based rate holders to make additional filings upon certain triggering events in order to maintain market based rate authority. The failure to make timely filings can result in revocation or suspension of market based rate authority, refunds of revenues previously collected and the imposition of civil penalties.

Under Section 203 of the FPA (“FPA Section 203”), prior authorization by FERC is generally required for any direct or indirect acquisition of control over, or merger or consolidation with, a “public utility” or in certain circumstances an “electric utility company,” as such terms are used for purposes of FPA Section 203. All of our renewable energy facilities that sell their output at wholesale in the continental U.S. (except in Texas) and Evergreen Gen Lead, LLC (which owns electric transmission facilities) are public utilities, and all are electric utility companies (including those in Texas) for the purposes of FPA Section 203. FERC generally presumes that the acquisition of direct or indirect voting power of 10% or more in an entity results in a change in control of such entity. Transfers of transmission facilities associated with our electric generation facilities or the whole of any such generation facility could also trigger the need to obtain prior approval from FERC under FPA Section 203. Violation of FPA Section 203 can result in civil or criminal liability under the FPA, including civil penalties, and the possible imposition of other sanctions by FERC. Depending upon the circumstances, liability for violation of FPA Section 203 may attach to a public utility, the parent holding company of a public utility or an electric utility company, or to an acquirer of the voting securities of such holding company or its public utility or electric utility company subsidiaries.

Certain of our renewable energy facilities are also subject to compliance with the mandatory Reliability Standards developed by the North American Electric Reliability Corporation (“NERC”) and approved by FERC. Violation of such Reliability Standards can result in civil penalties under the FPA assessed to the owners and/or operators of such renewable energy facilities. In the United Kingdom, Canada and Chile, the Company is also generally subject to the regulations of the relevant energy regulatory agencies applicable to all producers of electricity under the relevant feed-in tariff or other governmental incentive programs (collectively “FIT”) (including the FIT rates); however it is generally not subject to regulation as a traditional public utility, i.e., regulation of our financial organization and rates other than FIT rates.

As the size of our portfolio grows, it may become subject to new or modified regulatory regimes that may impose unanticipated requirements on its business as a whole that were not anticipated with respect to any individual renewable energy facility. For example, the NERC rules approved by FERC impose fleetwide cyber security requirements regarding electronic and physical access to generating facilities in order to protect system reliability; such requirements expand in scope after the point at which a single owner has more than 1,500 MW of reliability assets under its control in a single connection and expand again once the owner has more than 3,000 MW under construction. Such future changes in our regulatory status or the makeup of our fleet could require it to incur materially higher costs which could have a material adverse impact on its financial performance or results of operations. Similarly, although we are not currently subject to regulation as an electric utility in the foreign markets in which we provide our renewable energy services, our regulatory position in these markets could change in the future. Any local, state, federal or international regulations could place significant restrictions on our ability to operate our business and execute our business plan by prohibiting or otherwise restricting the sale of electricity by us. If we were deemed to be subject to the same state, federal or foreign regulatory authorities as traditional utility companies, or if new regulatory bodies were established to oversee the renewable energy industry in the United States or in our foreign markets, our operating costs could materially increase, adversely affecting our results of operations.

Government Incentives and Legislation

Each of the countries in which we operate has established various incentives and financial mechanisms to reduce the cost of renewable energy and to accelerate the adoption of solar and wind energy. These incentives include tax credits, cash grants, favorable tax treatment and depreciation, rebates, RECs or green certificates, net energy metering programs and other incentives. These incentives help catalyze private sector investments in renewable energy and efficiency measures. Changes in the government incentives in each of these jurisdictions could have a material impact on our financial performance.

United States

Federal government support for renewable energy

On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”). The Tax Act makes broad and complex changes to the U.S. tax code, including, but not limited to, (i) reducing the U.S. federal corporate rate from 35% to 21%; (ii) requiring companies to pay a one-time transition tax on certain unrepatriated earnings (where applicable) of foreign subsidiaries; (iii) generally eliminating the U.S. federal income tax on dividends received from foreign subsidiaries; (iv) requiring current inclusion in the U.S. federal taxable income


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of certain earnings of controlled foreign corporations; (v) eliminating the corporate alternative minimum tax (“AMT”) and changing how existing AMT credits may be realized; (vi) creating the base erosion anti-abuse tax (“BEAT”), a new minimum tax; (vii) creating a new limitation on the deductible interest expense; and (viii) changing rules related to uses and limitations of net operating loss carryforwards created in tax years beginning after December 31, 2017. The Tax Act is expected to have a neutral effect on our current business portfolio. The federal corporate tax rate reduction is expected to have a favorable impact on our business but this favorable impact is expected to be offset by a more or less equal negative impact of the interest expense deduction and loss carryforward limitations. The other measures of the Tax Act are not expected to significantly impact our current portfolio.

The U.S. federal government provides an uncapped investment tax credit, or “Federal ITC,” that allows a taxpayer to claim a credit of 30% of qualified expenditures for a residential or commercial solar generation facility. The Tax Act did not make any changes to the existing laws surrounding tax credits for renewable energy. The Federal ITC is currently scheduled to be reduced to 26% for solar generation facility construction that begins on or after January 1, 2020 and to 22% for solar generation facility construction that begins on or after January 1, 2021. A permanent 10% Federal ITC is available for non-residential solar generation facility construction that begins on or after January 1, 2022.

Certain wind facilities are eligible for PTCs, which are federal income tax credits related to the quantity of renewable energy produced and sold during a taxable year, or ITCs in lieu of PTCs. These credits are available only for wind power plants that began construction on or prior to December 31, 2019 but are reduced over time. The wind PTC (and ITC in lieu of PTC) are 100% in the case of a facility for which construction began by December 31, 2016, 80% in the case of any facility for which construction began in 2017, 60% in the case of a facility for which construction begins in 2018, and 40% in the case of a facility for which construction begins in 2019. ITCs, PTCs and accelerated tax depreciation benefits generated by constructing and operating renewable energy facilities can be monetized by entering into tax equity financing agreements with investors that can utilize the tax benefits, which have been a key financing tool for renewable energy facilities. The federal government also provides accelerated depreciation for eligible renewable energy facilities. Based on our portfolio of assets, we will benefit from Federal ITC, Federal PTC and an accelerated tax depreciation schedule, and we will rely on financing structures that monetize a substantial portion of these benefits and provide financing for our renewable energy facilities at the lowest cost of capital.

U.S. state government support for renewable energy
    
Many states offer a personal and/or corporate investment or production tax credit for renewable energy facilities, which is additive to the Federal ITC. Further, more than half of the states, and many local jurisdictions, have established property tax incentives for renewable energy facilities that include exemptions, exclusions, abatements and credits. Certain of our renewable energy facilities in the U.S. have been financed with a tax equity financing structure, whereby the tax equity investor is a member holding equity in the limited liability company that directly or indirectly owns the solar generation facility or wind power plant and receives the benefits of various tax credits.

Many state governments, utilities, municipal utilities and co-operative utilities offer a rebate or other cash incentive for the installation and operation of a renewable energy facility for energy efficiency measures. Capital costs or “up-front” rebates provide funds to solar customers based on the cost, size or expected production of a customer’s renewable energy facility. Performance-based incentives provide cash payments to a system owner based on the energy generated by their renewable energy facility during a pre-determined period, and they are paid over that time period. Some states also have established FIT programs that are a type of performance-based incentive where the system owner-producer is paid a set rate for the electricity their system generates over a set period of time.

There are 40 states that have a regulatory policy known as net metering. Net metering typically allows our customers to interconnect their on-site solar generation facilities to the utility grid and offset their utility electricity purchases by receiving a bill credit at the utility’s retail rate for energy generated by their solar generation facility in excess of electric load that is exported to the grid. At the end of the billing period, the customer simply pays for the net energy used or receives a credit at the retail rate if more energy is produced than consumed. Some states require utilities to provide net metering to their customers until the total generating capacity of net metered systems exceeds a set percentage of the utilities’ aggregate customer peak demand.

Many states also have adopted procurement requirements for renewable energy production. There are 29 states that have adopted a renewable portfolio standard (“RPS”) that requires regulated utilities to procure a specified percentage of total electricity delivered to customers in the state from eligible renewable energy sources, such as solar and wind power generation facilities, by a specified date. To prove compliance with such mandates, utilities must procure and retire RECs. System owners often are able to sell RECs to utilities directly or in REC markets.



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RPS programs and targets have been one of the key drivers of the expansion of solar and wind power and are expected to continue to contribute to solar and wind power installations in many areas of the United States. In addition to the 29 states with RPS programs, eight other states have non-binding goals supporting renewable energy.

International

The international markets in which we operate or may operate in the future also typically have in place regimes to promote renewable energy. These mechanisms vary from country to country. Our objective is to grow our dividend through the growth of our portfolio in North America and Western Europe, including through our recently announced tender offer to acquire Saeta Yield, S.A., a Spanish corporation, that is expected to close in the second quarter of 2018 (as described below under Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield). In seeking to achieve this growth, we may rely on governmental incentives in these jurisdictions. For example, a meaningful portion of our existing portfolio is located in the Canadian province of Ontario. With installed capacity of approximately 4,800 MW of wind and 2,300 MW of solar, Ontario, one of our provincial markets, leads Canada in installed wind and solar power capacity. While the current Long Term Energy Plan for Ontario, released in October 2017, no longer specifies targets for renewable energy, it continues to focus on measures supporting innovation and grid modernization, including in respect of renewable distributed generation.

Financial Information about Segments

We have two reportable segments: Solar and Wind. These segments comprise our entire portfolio of renewable energy assets and are determined based on the management approach. This approach designates the internal reporting used by management for making decisions and assessing performance as the source of the reportable segments. Our operating segments consist of Distributed Generation, North America Utility and International Utility that are aggregated into the Solar reportable segment and Northeast Wind, Central Wind and Hawaii Wind that are aggregated into the Wind reportable segment. The operating segments have been aggregated as they have similar economic characteristics and meet all of the aggregation criteria. Corporate expenses include general and administrative expenses, acquisition costs, interest expense on corporate-level indebtedness, stock-based compensation, depreciation, accretion and amortization expense and loss on extinguishment of corporate-level indebtedness. All net operating revenues for the years ended December 31, 2017, 2016 and 2015 were earned by our reportable segments from external customers in the United States (including Puerto Rico), Canada, the United Kingdom and Chile.

Customer Concentration

For the year ended December 31, 2017, significant customers representing greater than 10% of total operating revenue were Tennessee Valley Authority and San Diego Gas & Electric, which accounted for 13.1% and 10.5%, respectively, of our consolidated operating revenues, net.

Employees

Prior to 2017, the Company did not have any of its own employees as the personnel that managed our operations were employees of SunEdison and their services were provided to the Company under the management services agreement or project-level asset management and O&M services agreements with SunEdison. Following the SunEdison Bankruptcy, as part of our efforts to create a stand-alone corporate organization, we established a retention program for key employees. As of January 1, 2017, the key employees that provided most of our corporate-level services were hired directly by the Company to ensure continuity of corporate operations, and throughout the first half of 2017, we hired additional employees from SunEdison who provided services to us, a majority of which focused on project-level operations. However, we continue to depend on a substantial number of outside contractors. As of December 31, 2017, we had 119 employees, the majority of which were located in the United States.

In connection with the expected relocation of our headquarters to New York, New York, we expect to experience departures of a significant number of these employees. 66 of the Company's employees as of December 31, 2017 are employed under short-term transition agreements, which range from three to nine months of service subsequent to the Merger closing date on October 16, 2017. In addition, we have experienced changes to our executive officers and senior management, including the departure of our interim Chief Executive Officer, Chief Financial Officer and General Counsel upon the closing of the Sponsorship Transaction. The governance agreements entered into between the Company and Brookfield in connection with the Merger and Sponsorship Transaction provide for Brookfield to appoint our Chief Executive Officer, Chief Financial Officer and General Counsel. These three executive officers are not employees of the Company and their services are provided pursuant to the Brookfield MSA.
    


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Geographic Information

The following table reflects operating revenues, net for the years ended December 31, 2017, 2016 and 2015 by geographic location:
 
 
Year Ended December 31,
(In thousands)
 
2017
 
2016
 
2015
United States (including Puerto Rico)
 
$
519,551

 
$
528,513

 
$
368,117

Chile
 
31,282

 
28,065

 
27,148

United Kingdom
 
15,002

 
51,600

 
55,542

Canada
 
44,636

 
46,378

 
18,699

Total operating revenues, net
 
$
610,471

 
$
654,556

 
$
469,506

    
Long-lived assets, net consist of renewable energy facilities and intangible assets as of December 31, 2017 and 2016. The following table is a summary of long-lived assets, net by geographic area:
 
 
As of December 31,
(In thousands)
 
2017
 
2016
United States (including Puerto Rico)
 
$
5,270,988

 
$
5,524,136

Chile
 
168,440

 
175,204

United Kingdom
 
17,284

 
16,045

Canada
 
422,999

 
419,978

Total long-lived assets, net
 
5,879,711

 
6,135,363

Current assets
 
341,536

 
893,016

Other non-current assets1
 
165,774

 
677,486

Total assets
 
$
6,387,021

 
$
7,705,865

———
(1)
As of December 31, 2016, includes $532.7 million and $19.5 million of non-current assets held for sale located in the United Kingdom and United States, respectively. There are no similar amounts as of December 31, 2017 as the sale of these renewable energy facilities closed in the first half of 2017.

Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield

On February 7, 2018, we announced that we intend to launch a voluntary tender offer (the “Tender Offer”) to acquire 100% of the outstanding shares of Saeta Yield, S.A. (“Saeta Yield”), a Spanish corporation and a publicly-listed European owner and operator of wind and solar assets, located primarily in Spain. The Tender Offer will be for 12.20 Euros per share of Saeta Yield. The Tender Offer is expected to be completed in the second quarter of 2018, subject to certain closing conditions.

In connection with this Tender Offer, on February 6, 2018, TERP Spanish HoldCo, S.L. (“TERP Spanish HoldCo”), a subsidiary of the Company, entered into an irrevocable undertaking agreement for the launch and acceptance of the takeover bid for the shares of Saeta Yield with Cobra Concesiones, S.L., a company incorporated under the laws of Spain (“Cobra”), and GIP II Helios, S.à r.l., a société à responsabilité limitée organized under the laws of the Grand Duchy of Luxembourg (“GIP”), as well as two separate irrevocable undertaking agreements with Mutuactivos, S.A.U., S.G.I.I.C., a company incorporated under the laws of Spain (“Mutuactivos”), and with Sinergia Advisors 2006, A.V., S.A., a company incorporated under the laws of Spain (“Sinergia” and, together with Cobra, GIP and Mutuactivos, the “Selling Stockholders”). Under the terms of these irrevocable undertaking agreements, the Selling Stockholders have irrevocably and unconditionally agreed to tender their combined 50.338% interest in Saeta Yield in the Tender Offer.

Our acceptance of the shares of Saeta Yield tendered in the Tender Offer is conditioned upon us obtaining compulsory authorization required from the European Commission and Cobra and GIP irrevocably accepting the Tender Offer in respect of their shares of Saeta Yield representing no less than 48.222% of Saeta Yield’s voting share capital.
    
The aggregate value of the shares of Saeta Yield held by the Selling Stockholders is approximately $600 million. If we successfully acquire all of the remaining Saeta Yield shares in the Tender Offer, the aggregate purchase price (including the value of the Selling Stockholders shares) will be approximately $1.2 billion. Assuming a $1.2 billion acquisition price, we


17


intend to finance the acquisition with a $400 million equity issuance of our Class A common stock (the “Equity Offering”) and the remaining $800 million will be financed from available liquidity, which we expect will include borrowings under the Sponsor Line Agreement and the New Revolver (as defined and discussed in Liquidity and Capital Resources within Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations). We expect to repay these borrowings with a combination of sources, including new non-recourse financings of our currently unencumbered wind and solar assets and certain cash released from Saeta Yield’s assets.

In connection with the launch of the Tender Offer, we were required to post a bank guarantee (the “Bank Guarantee”) with the Spanish National Securities Market Commission (Comisión Nacional del Mercado de Valores) (the “CNMV”) for the maximum amount payable in the Tender Offer of approximately $1.2 billion. On March 6, 2018, TERP Spanish HoldCo entered into two letter of credit facilities (the “LC Agreements”) pursuant to which two banks posted the Bank Guarantee with the CNMV for the maximum amount payable in the Tender Offer. On March 6, 2018, TerraForm Power entered into two letter agreements (the “Letter Agreements” and together with the LC Agreements, the “Letter of Credit Facilities”) with those banks. The LC Agreements govern TERP Spanish HoldCo’s obligations to reimburse those banks upon any drawing under the Bank Guarantee. The Letter Agreements govern TerraForm Power’s obligation to utilize drawings on its New Revolver and Sponsor Line Agreement or proceeds from an equity offering of its Class A common stock to contribute funds to TERP Spanish HoldCo to enable TERP Spanish HoldCo to satisfy its reimbursement obligations under the LC Agreements. The Letter of Credit Facilities also contain customary fees, representations and warranties, covenants and events of default. Under the terms of the Letter of Credit Facilities, we are required to maintain minimum liquidity requirements of $500.0 million under the Sponsor Line Agreement and $400.0 million under the New Revolver. In addition, if any amount is drawn under the Bank Guarantee, or if an event of default occurs under the Letter of Credit Facilities, we may be required to cash collateralize the entire amount of the Bank Guarantee that has not been drawn.

Saeta Yield's portfolio is comprised of 100% owned, recently constructed assets located primarily in Spain with additional assets located in Portugal and Uruguay, including 778 MW of onshore wind and 250 MW of concentrated solar, with an average age of six years and a remaining useful life in excess of 25 years as of the date of our tender offer announcement. 100% of Saeta Yield's revenues are generated under stable frameworks with investment grade counterparties. Over 80% of Saeta Yield's revenues are regulated under the Spanish renewable power regime with limited resource and market price risk, and the remaining 20% of revenues are under long-term power purchase or concession agreements. Saeta Yield's revenues have an average remaining regulatory/contractual term of 15 years.

Backstop Agreement with Brookfield

On February 6, 2018, we entered into a support agreement with Brookfield. Pursuant to this agreement, Brookfield agreed that, if requested by us, Brookfield would provide a back-stop to us for up to 100% of the Equity Offering (such agreement, the “Back-Stop”) if the offering price per Class A share of our common stock in the Equity Offering equals the five-day volume weighted average price of the Class A shares ending the trading day prior to our announcement of the Tender Offer, which was $10.66 per share. Brookfield’s obligations in relation to the provision of the Back-Stop under the support agreement are subject to successful commencement of the Tender Offer and to prior effectiveness of a registration statement, if required, that we would file in connection with the Equity Offering and such obligation would not apply to any Equity Offering commenced prior to May 1, 2018 or after September 30, 2018.

Available Information

We make available free of charge through our website (www.terraformpower.com) the reports we file with the SEC, including our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. The SEC maintains an internet site containing these reports and proxy and information statements at http://www.sec.gov. Any materials we file can be read and copied online at that site or at the SEC's Public Reference Room at 100 F Street, NE, Washington DC 20549, on official business days during the hours of 10:00 am and 3:00 pm. Information on the operation of the Public Reference Room can be obtained by calling the SEC at 1-800-SEC-0330.

The following corporate governance documents are posted on our website at www.terraformpower.com:
The TerraForm Power, Inc. Audit Committee Charter;
The TerraForm Power, Inc. Code of Business Conduct and Ethics;
The TerraForm Power, Inc. Conflicts Committee Charter;
The TerraForm Power, Inc. Anti-Bribery and Corruption Policy;
The TerraForm Power, Inc. Nominating and Corporate Governance Committee Charter; and


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The TerraForm Power, Inc. Board of Directors Charter.
    
If you would like a printed copy of any of these corporate governance documents, please send your request to 7550 Wisconsin Avenue, 9th Floor, Bethesda, Maryland 20814.

The information on our website is not incorporated by reference into this Annual Report on Form 10-K and does not constitute part of this Annual Report on Form 10-K.

Item 1A. Risk Factors.

The following pages discuss the principal risks we face. Any of these risk factors could have a significant or material adverse effect on our businesses, results of operations, financial condition or liquidity. They could also cause significant fluctuations and volatility in the trading price of our securities. Readers should not consider any descriptions of these factors to be a complete set of all potential risks and uncertainties that could affect us. These factors should be considered carefully together with the other information contained in this Annual Report on Form 10-K and the other reports and materials filed by us with the SEC. Furthermore, many of these risks are interrelated, and the occurrence of certain of them may in turn cause the emergence or exacerbate the effect of others. Such a combination could materially increase the severity of the impact of these risks on our businesses, results of operations, financial condition and liquidity.

Risks Related to Our Business

We may not realize the expected benefits of the Merger and Sponsorship Transaction.

Following the closing of the Merger and Sponsorship Transaction, the Company may not perform as we expect, or as the market expects, which could have an adverse effect on the price of our Class A common stock. Concurrently with the closing of the Merger and Sponsorship Transaction, Brookfield and the Company entered into the new sponsorship agreements, which include, among other things, for Brookfield to provide strategic and investment management services to the Company, for Brookfield, subject to certain terms and conditions, to provide the Company with a right of first offer on certain operating wind and solar assets that are located in North America and Western Europe and developed by persons sponsored by or under the control of Brookfield and for Brookfield to provide TerraForm Power with a $500 million secured revolving credit facility to fund certain acquisitions or growth capital expenditures.

The Company may not realize expected benefits of Brookfield’s management services and the other aspects of the sponsorship arrangements. For example, the Company may fail to realize expected operational or margin improvements, synergies or other cost savings or reductions, may not achieve expected growth in its portfolio through organic growth or third-party acquisitions and may not be able to acquire assets from Brookfield. The Company may also not be able to effectively utilize the $500 million revolving credit facility provided by Brookfield for accretive acquisitions or at all. Our failure to realize these aspects of the Sponsorship Transaction may have an adverse effect on the price of our Class A common stock and on our business, growth and the results of our operations.

The Merger and Sponsorship Transaction and related uncertainty could cause disruptions in our business, which could have an adverse effect on our business and financial results and the price of our Class A common stock.

We have important counterparties at every level of operations, including offtakers under our PPAs, corporate and project-level lenders and tax equity investors, suppliers and service providers. Uncertainty about the effect of the sponsorship with Brookfield may negatively affect our relationship with our counterparties due to concerns about the Brookfield sponsorship and its impact on our business. These concerns may cause counterparties to be more likely to reduce utilization of our services (or the provision of supplies or services) where the counterparty has flexibility in volume or duration or otherwise seeks to change the terms on which they do business with us. These concerns may also cause our existing or potential new counterparties to be less likely to enter into new agreements or to demand more expensive or onerous terms, credit support, security or other conditions. Damage to our existing or potential future counterparty relationships may materially and adversely affect our business, financial condition and results of operations, including our growth strategy and the price of our Class A common stock.
    
The production of wind energy depends heavily on suitable wind conditions, and the production of solar depends on irradiance, which is the amount of solar energy received at a particular site. If wind or solar conditions are unfavorable or below our estimates, our electricity production, and therefore our revenue, may be substantially below our expectations.

The electricity produced and revenues generated by a wind power plant depend heavily on wind conditions, which are


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variable and difficult to predict. Operating results for wind power plants vary significantly from period to period depending on the wind conditions during the periods in question. The electricity produced and the revenues generated by a solar power plant depends heavily on insolation, which is the amount of solar energy received at a site. While somewhat more predictable than wind conditions, operating results for solar power plants can also vary from period to period depending on the solar conditions during the periods in question. We have based our decisions about which sites to develop in part on the findings of long-term wind, irradiance and other meteorological data and studies conducted in the proposed area, which, as applicable, measure the wind’s speed and prevailing direction, the amount of solar irradiance a site is expected to receive and seasonal variations. Actual conditions at these sites, however, may not conform to the measured data in these studies and may be affected by variations in weather patterns, including any potential impact of climate change. Therefore, the electricity generated by our power plants may not meet our anticipated production levels or the rated capacity of the turbines or solar panels located there, which could adversely affect our business, financial condition and results of operations. In some quarters the wind resources at our operating wind power plants, while within the range of our long-term estimates, have varied from the averages we expected. If the wind or solar resources at a facility are below the average level we expect, our rate of return for the facility would be below our expectations and we would be adversely affected. Projections of wind resources also rely upon assumptions about turbine placement, interference between turbines and the effects of vegetation, land use and terrain, which involve uncertainty and require us to exercise considerable judgment. Projections of solar resources depend on assumptions about weather patterns (including snow), shading, and other assumptions which involve uncertainty and also require us to exercise considerable judgment. We or our consultants may make mistakes in conducting these wind, irradiance and other meteorological studies. Any of these factors could cause our sites to have less wind or solar potential than we expected and may cause us to pay more for wind and solar power plants in connection with acquisitions than we otherwise would have paid had such mistakes not been made, which could cause the return on our investment in these wind and solar power plants to be lower than expected.

If our wind and solar energy assessments turn out to be wrong, our business could suffer a number of material adverse consequences, including:

our energy production and sales may be significantly lower than we predict;
our hedging arrangements may be ineffective or more costly;
we may not produce sufficient energy to meet our commitments to sell electricity or RECs and, as a result, we may have to buy electricity or RECs on the open market to cover our obligations or pay damages; and
our wind and solar power plants may not generate sufficient cash flow to make payments of principal and interest as they become due on the notes and our non-recourse debt, and we may have difficulty obtaining financing for future wind power plants.

Our failure to achieve and maintain effective internal control over financial reporting in accordance with Section 404 of the Sarbanes-Oxley Act could have a material adverse effect on our business and share price.

We are required to comply with Section 404(a) of the Sarbanes-Oxley Act in the course of preparing our financial statements, and our management is required to report on the effectiveness of our internal control over financial reporting for such year. Additionally, our independent registered public accounting firm is required pursuant to Section 404(b) of the Sarbanes-Oxley Act to attest to the effectiveness of our internal control over financial reporting on an annual basis. The rules governing the standards that must be met for our management to assess our internal control over financial reporting are complex and require significant documentation, testing and possible remediation.

Internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with GAAP. A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the entity’s financial statements will not be prevented or detected on a timely basis. The existence of any material weakness would require management to devote significant time and incur significant expense to remediate any such material weaknesses and management may not be able to remediate any such material weaknesses in a timely manner.

As of December 31, 2017, we did not maintain an effective control environment attributable to certain identified material weaknesses. We describe these material weaknesses in Item 9A. Controls and Procedures in this Annual Report on Form 10-K. These control deficiencies create a reasonable possibility that a material misstatement to the consolidated financial statements will not be prevented or detected on a timely basis, and therefore we concluded that the deficiencies represent material weaknesses in the Company’s internal control over financial reporting and our internal control over financial reporting


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was not effective as of December 31, 2017.

The existence of these or other material weakness in our internal control over financial reporting could also result in errors in our financial statements that could require us to restate our financial statements, cause us to fail to meet our reporting obligations and cause stockholders to lose confidence in our reported financial information, all of which could materially and adversely affect our business and stock price.

We are involved in costly and time-consuming litigation and other regulatory proceedings which require significant attention from our management, which involve a greater exposure to legal liability and may result in significant damage awards and which may relate to the operations of our renewable energy facilities.

We have been and continue to be involved in legal proceedings, administrative proceedings, claims and other litigation that arise in the ordinary course of business, including proceedings related to the operation of our renewable energy facilities. For example, individuals or groups have in the past and may in the future challenge the issuance of a permit for a renewable energy facility or may make claims related to alleged impacts of the operation of our renewable energy facilities on adjacent properties. In addition, we are named as defendants from time to time in other lawsuits and regulatory actions relating to our business, some of which may claim significant damages. We have also been subject to claims arising out of our acquisition activities with respect to certain payments in connection with the acquisition of First Wind by SunEdison.

Due to the inherent uncertainties of litigation and regulatory proceedings, we cannot accurately predict the ultimate outcome of any such proceedings. Unfavorable outcomes or developments relating to these proceedings, or new proceedings involving similar allegations or otherwise, such as monetary damages or equitable remedies, could have a material adverse impact on our business and financial position, results of operations or cash flows or limit our ability to engage in certain of our business activities. Settlement of claims could adversely affect our financial condition, results of operations and cash flows. In addition, regardless of the outcome of any litigation or regulatory proceedings, such proceedings are often expensive, lengthy and disruptive to normal business operations and require significant attention from our management. We are currently and/or may be subject in the future to claims, lawsuits or arbitration proceedings related to matters in tort or under contracts, employment matters, securities class action lawsuits, shareholder derivative actions, breaches of fiduciary duty, conflicts of interest, tax authority examinations or other lawsuits, regulatory actions or government inquiries and investigations.

In the past, companies that have experienced volatility in the market price of their stock have been subject to securities class action litigation. We have been the target of such securities litigation in the past (see Note 19. Commitments and Contingencies to our consolidated financial statements, included in this Annual Report on Form 10-K) and we may become the target of additional securities litigation in the future, which could result in substantial costs and divert our management’s attention from other business concerns, which could have a material adverse effect on our business.

The settlement of certain existing litigation will trigger a requirement to issue additional Class A common stock to Brookfield.

We have agreed, in the Merger Agreement, to issue additional shares of Class A common stock to Brookfield for no additional consideration in respect of the final resolution of certain specified litigation (see Note 19. Commitments and Contingencies to our consolidated financial statements for a description of such litigation). The number of additional shares of Class A common stock to be issued to Brookfield is subject to a pre-determined formula as set forth in the Merger Agreement as described in greater detail in the Company's Definitive Proxy Statement filed on Schedule 14A with the SEC on September 6, 2017 and will compensate Brookfield for the total amount of losses we incur with respect to such specified litigation. The number of shares of Class A common stock to be issued to Brookfield could be significant, resulting in the dilution of the ownership interests of our remaining Class A common stockholders.

A significant portion of our assets consists of long-lived assets, the value of which may be reduced if we determine that those assets are impaired.
    
As of December 31, 2017, the net carrying value of long-lived assets represented $5,879.7 million, or 92%, of our total assets and consisted of renewable energy facilities and intangible assets. Renewable energy facilities and intangible assets are reviewed for impairment whenever events or changes in circumstances indicate carrying values may not be recoverable. An impairment loss is recognized if the total future estimated undiscounted cash flows expected from an asset are less than its carrying value.

As a result of classifying substantially all of our portfolio of residential rooftop solar assets located in the United States as held for sale during the fourth quarter of 2016 and determining that the carrying value exceeded the fair value less


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costs to sell, we recorded an impairment charge of $15.7 million within impairment of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2016. We also recorded a $3.3 million charge within impairment of renewable energy facilities for the year ended December 31, 2016 due to the decision to abandon certain residential construction in progress assets that were not completed by SunEdison as a result of the SunEdison Bankruptcy. In 2017, we recorded an additional $1.4 million charge within impairment of renewable energy facilities related to our remaining 0.3 MW of residential assets that were not classified as held for sale as of December 31, 2016 as we determined certain impairment indicators were present.
During 2016, our long-lived assets also included goodwill but based on our annual goodwill impairment testing conducted as of December 1, 2016, and a review of any potential indicators of impairment, we concluded that the carrying value of $55.9 million was impaired and it was fully written off in 2016. There have been no impairments of intangible assets to date. If intangible assets or additional renewable energy facilities are impaired based on a future impairment test, we could be required to record further non-cash impairment charges to our operating income. Such non-cash impairment charges, if significant, could materially and adversely affect our results of operations in the period recognized.
Counterparties to our PPAs may not fulfill their obligations or may seek to terminate the PPA early, which could result in a material adverse impact on our business, financial condition, results of operations and cash flows.

All but a minor portion of the electricity generated by our current portfolio of renewable energy facilities is sold under long-term PPAs, including power purchase agreements with public utilities or commercial, industrial or government end-users or hedge agreements with investment banks and creditworthy counterparties. Certain of the PPAs associated with renewable energy facilities in our portfolio allow the offtake purchaser to terminate the PPA in the event certain operating thresholds or performance measures are not achieved within specified time periods or, in certain instances, by payment of an early termination fee. If a PPA was terminated or if, for any reason, any purchaser of power under these contracts is unable or unwilling to fulfill their related contractual obligations or refuses to accept delivery of power delivered thereunder, and if we are unable to enter a new PPA on acceptable terms in a timely fashion or at all, we would be required to sell the power from the associated renewable energy facility into the wholesale power markets, which could have a material adverse effect on our business, financial condition, results of operations and cash flows. Moreover, seeking to enforce the obligations of our counterparties under our PPAs could be time consuming or costly and could involve little certainty of success.

Certain of our PPAs allow the offtake purchaser to buy out a portion of the renewable energy facility upon the occurrence of certain events, in which case we will need to find suitable replacement renewable energy facilities to invest in.

Certain of the PPAs for renewable energy facilities in our portfolio or that we may acquire in the future allow the offtake purchaser to purchase all or a portion of the applicable renewable energy facility from us. If the offtake purchaser exercises its right to purchase all or a portion of the renewable energy facility, we would need to reinvest the proceeds from the sale in one or more renewable energy facilities with similar economic attributes in order to maintain our cash available for distribution. If we were unable to locate and acquire suitable replacement renewable energy facilities in a timely fashion it could have a material adverse effect on our results of operations and cash available for distribution.

Most of our PPAs do not include inflation-based price increases.

In general, our PPAs do not contain inflation-based price increase provisions. To the extent that the countries in which we operate experience high rates of inflation, which increases our operating costs in those countries, we may not be able to generate sufficient revenues to offset the effects of inflation, which could materially and adversely affect our business, financial condition, results of operations and cash flows.

A material drop in the retail price of utility-generated electricity or electricity from other sources could limit our ability to attract new customers and adversely affect our growth.

Decreases in the retail prices of electricity supplied by utilities or other clean energy sources would harm our ability to offer competitive pricing and could harm our ability to sign PPAs with customers. The price of electricity from utilities could decrease for a number of reasons, including:

the construction of a significant number of new power generation plants, including nuclear, coal, natural gas or renewable energy facilities;
the construction of additional electric transmission and distribution lines;


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a reduction in the price of natural gas, including as a result of new drilling techniques or a relaxation of associated regulatory standards;
energy conservation technologies and public initiatives to reduce electricity consumption; and
the development of new clean energy technologies that provide less expensive energy.

A shift in the timing of peak rates for utility-supplied electricity to a time of day when solar energy generation is less efficient could make solar energy less competitive and reduce demand. If the retail price of energy available from utilities were to decrease, we would be at a competitive disadvantage in negotiating new PPAs and therefore we may be unable to attract new customers and our growth would be limited, and the value of our renewable energy facilities may be impaired or their useful life may be shortened.

We may not be able to replace expiring PPAs with contracts on similar terms. If we are unable to replace an expired distributed generation PPA with an acceptable new contract, we may be required to remove the renewable energy facility from the site or, alternatively, we may sell the assets to the site host.

We may not be able to replace an expiring PPA with a contract on equivalent terms and conditions, including at prices that permit operation of the related facility on a profitable basis. If we are unable to replace an expiring PPA with an acceptable new revenue contract, the affected site may temporarily or permanently cease operations or we may be required to sell the power produced by the facility at wholesale prices which are exposed to market fluctuations and risks. In the case of a distributed generation solar facility that ceases operations, the PPA terms generally require that we remove the assets, including fixing or reimbursing the site owner for any damages caused by the assets or the removal of such assets. The cost of removing a significant number of distributed generation solar facilities could be material. Alternatively, we may agree to sell the assets to the site owner, but the terms and conditions, including price that we would receive in any sale and the sale price may not be sufficient to replace the revenue previously generated by the solar generation facility.

Our ability to generate revenue from certain utility-scale solar and wind power plants depends on having interconnection arrangements and services and the risk of curtailment of our renewable energy facilities may result in a reduced return to us on our investments and adversely impact our business, financial condition, and results of operations.

The operation of our utility scale renewable energy facilities depends on having interconnection arrangements with transmission providers and depends on a reliable electricity grid. If the interconnection or transmission agreement of a renewable energy facility we own or acquire is terminated for any reason, we may not be able to replace it with an interconnection or transmission arrangement on terms as favorable as the existing arrangement, or at all, or we may experience significant delays or costs in securing a replacement. Moreover, if a transmission network to which one or more of our existing power plants or a power plant we acquire is connected experiences “down time,” the affected renewable energy facility may lose revenue and be exposed to non-performance penalties and claims from its customers. Curtailment as a result of transmission system down time can arise from the need to prevent damage to the transmission system and for system emergencies, force majeure, safety, reliability, maintenance or other operational reasons. Under our power purchase arrangements, our offtakers are not generally required to compensate us for energy and ancillary services we could have delivered during these periods of curtailment had our facilities not been curtailed. Further, the owners of the transmission network will not usually compensate electricity generators for lost income due to curtailment. These factors could materially affect our ability to forecast operations and negatively affect our business, results of operations, financial condition and cash flows.

In addition, we cannot predict whether transmission facilities will be expanded in specific markets to accommodate or increase competitive access to those markets. Expansion of the transmission system by transmission providers is costly, time consuming and complex. To the extent the transmission system is not adequate in an area, our operating facilities’ generation of electricity may be physically or economically curtailed without compensation due to transmission capacity limitations, reducing our revenues and impairing our ability to capitalize fully on a particular facility’s generating potential. Such curtailments could have a material adverse effect on our business, financial condition, results of operations and cash flows. Furthermore, economic congestion on the transmission grid (for instance, a positive price difference between the location where power is put on the grid by a clean power generation asset and the location where power is taken off the grid by the facility’s customer) in certain of the bulk power markets in which we operate may occur and we may be deemed responsible for those congestion costs. If we were liable for such congestion costs, our financial results could be adversely affected.

We face competition from traditional and renewable energy companies.

The solar and wind energy industries, and the broader clean energy industry, are highly competitive and continually


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evolving, as market participants strive to distinguish themselves within their markets and compete with large incumbent utilities and new market entrants. We believe that our primary competitors are the traditional incumbent utilities that supply energy to our potential customers under highly regulated rate and tariff structures. We compete with these traditional utilities primarily based on price, predictability of price and the ease with which customers can switch to electricity generated by our renewable energy facilities. If we cannot offer compelling value to our customers based on these factors, then our business will not grow. Traditional utilities generally have substantially greater financial, technical, operational and other resources than we do, and as a result may be able to devote more resources to the research, development, promotion and sale of their products or respond more quickly to evolving industry standards and changes in market conditions than we can. Traditional utilities could also offer other value-added products or services that could help them to compete with us even if the cost of electricity they offer is higher than ours. In addition, the source of a majority of traditional utilities’ electricity is non-renewable, which may allow them to sell electricity more cheaply than electricity generated by our solar generation facilities, wind power plants, and other types of clean power generation assets we may acquire.

We also face risks that traditional utilities could change their volumetric-based (i.e., cents per kWh) rate and tariff structures to make distributed solar generation less economically attractive to their retail customers. Currently, net metering programs are utilized in the majority of states to support the growth of distributed generation solar facilities by requiring traditional utilities to reimburse certain of their retail customers for the excess power they generate at the level of the utilities’ retail rates rather than the rates at which those utilities buy power at wholesale. In Arizona, the state has allowed its largest traditional utility, Arizona Public Service, to assess a surcharge on customers with solar generation facilities for their use of the utility’s grid, based on the size of the customer’s solar generation facility. This surcharge will reduce the economic returns for the excess electricity that the solar generation facilities produce. These types of changes or other types of changes that could reduce or eliminate the economic benefits of net metering could be implemented in other states, which could significantly change the economic benefits of solar energy as perceived by traditional utilities’ retail customers.

We also face competition in the energy efficiency evaluation and upgrades market and we expect to face competition in additional markets as we introduce new energy-related products and services. As the solar and wind industries grow and evolve, we will also face new competitors who are not currently in the market. Our failure to adapt to changing market conditions and to compete successfully with existing or new competitors could limit our growth and could have a material adverse effect on our business and prospects.

There are a limited number of purchasers of utility-scale quantities of electricity, which exposes us and our utility-scale facilities to additional risk.

Since the transmission and distribution of electricity is either monopolized or highly concentrated in most jurisdictions, there are a limited number of possible purchasers for utility-scale quantities of electricity in a given geographic location, including transmission grid operators, state and investor-owned power companies, public utility districts and cooperatives. As a result, there is a concentrated pool of potential buyers for electricity generated by our renewable energy facilities, which may restrict our ability to negotiate favorable terms under new PPAs and could impact our ability to find new customers for the electricity generated by our renewable energy facilities should this become necessary. Furthermore, if the financial condition of these utilities and/or power purchasers deteriorated or the RPS programs, climate change programs or other regulations to which they are currently subject and that compel them to source renewable energy supplies change, demand for electricity produced by our utility-scale facilities could be negatively impacted.

Our hedging activities may not adequately manage our exposure to commodity and financial risk, which could result in significant losses or require us to use cash collateral to meet margin requirements, each of which could have a material adverse effect on our business, financial condition, results of operations and liquidity, which could impair our ability to execute favorable financial hedges in the future.

Certain of our wind power plants are party to financial swaps or other hedging arrangements. We may also acquire additional assets with similar hedging arrangements in the future. Under the terms of the existing financial swaps, certain wind power plants are not obligated to physically deliver or purchase electricity. Instead, they receive payments for specified quantities of electricity based on a fixed-price and are obligated to pay the counterparty the market price for the same quantities of electricity. These financial swaps cover quantities of electricity that we estimated are highly likely to be produced. As a result, gains or losses under the financial swaps are designed to be offset by decreases or increases in a facility’s revenues from spot sales of electricity in liquid markets. However, the actual amount of electricity a facility generates from operations may be materially different from our estimates for a variety of reasons, including variable wind conditions and wind turbine availability. If a wind power plant does not generate the volume of electricity covered by the associated swap contract, we could incur significant losses if electricity prices in the market rise substantially above the fixed-price provided for in the swap. If a wind power plant generates more electricity than is contracted in the swap, the excess production will not be hedged and


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the related revenues will be exposed to market price fluctuations.

Moreover, in some power markets, at times we have experienced negative power prices with respect to merchant energy sales. In these situations, we must pay grid operators to take our power. Because our tax investors receive production tax credits from the production of energy from our wind plants, it may be economical for the plant to continue to produce power at negative prices, which results in our wind facility paying for the power it produces. In addition, certain of these financial or hedging arrangements are financially settled with reference to energy prices (or locational marginal prices) at a certain hub or node on the transmission system in the relevant energy market. At the same time, revenues generated by physical sales of energy from the applicable facility may be determined by the energy price (or locational marginal price) at a different node on the transmission system. This is an industry practice used to address the lack of liquidity at individual facility locations. There is a risk, however, that prices at these two nodes differ materially, and as a result of this so called “basis risk,” we may be required to settle our financial hedges at prices that are higher than the prices at which we are able to sell physical power from the applicable facility, thus reducing the effectiveness of the swap hedges.

We are exposed to foreign currency exchange risks because certain of our renewable energy facilities are located in foreign countries.

We generate a portion of our revenues and incur a portion of our expenses in currencies other than U.S. dollars. The portion of our revenues generated in currencies other than U.S. dollars is expected to increase substantially if we complete the Tender Offer for the shares of Saeta Yield and may otherwise increase in the future. Changes in economic or political conditions in any of the countries in which we operate now or in the future could result in exchange rate movement, new currency or exchange controls or other restrictions being imposed on our operations or expropriation. As our financial results are reported in U.S. dollars, if we generate revenue or earnings in other currencies, the translation of those results into U.S. dollars can result in a significant increase or decrease in the amount of those revenues or earnings. To the extent that we are unable to match revenues received in foreign currencies with costs paid in the same currency, exchange rate fluctuations in any such currency could have a negative impact on our profitability. Our debt service requirements are primarily in U.S. dollars even though a percentage of our cash flow is generated in other foreign currencies and therefore significant changes in the value of such foreign currencies relative to the U.S. dollar could have a material negative impact on our financial condition and our ability to meet interest and principal payments on debts denominated in U.S. dollars. In addition to currency translation risks, we incur currency transaction risks whenever we or one of our facilities enter into a purchase or sales transaction using a currency other than the local currency of the transacting entity.

Given the volatility of exchange rates, we cannot assure you that we will be able to effectively manage our currency transaction and/or translation risks. It is possible that volatility in currency exchange rates will have a material adverse effect on our financial condition or results of operations. We expect to experience economic losses and gains and negative and positive impacts on earnings as a result of foreign currency exchange rate fluctuations, particularly as a result of changes in the value of the Canadian dollar, the British pound and other currencies.

Additionally, although a portion of our revenues and expenses are denominated in foreign currency, any dividends we pay will be denominated in U.S. dollars. The amount of U.S. dollar denominated dividends paid to our holders of our Class A common stock will therefore be exposed to a certain level of currency exchange rate risk. Although we have entered into certain hedging arrangements to help mitigate some of this exchange rate risk, these arrangements may not be sufficient to eliminate the risk. Changes in the foreign exchange rates could have a material negative impact on our results of operations and may adversely affect the amount of cash dividends paid by us to holders of our Class A common stock.

A portion of our revenues is attributable to the sale of renewable energy credits and solar renewable energy credits, which are renewable energy attributes that are created under the laws of individual states of the United States, and our failure to be able to sell such RECs or SRECs at attractive prices, or at all, could materially adversely affect our business, financial condition and results of operation.
    
A portion of our revenues is attributable to our sale of RECs and other environmental attributes of our facilities which are created under the laws of the state of the United States where the facility is located. We sometimes seek to sell forward a portion of our RECs or other environmental attributes under contracts having terms in excess of one year to fix the revenues from those attributes and hedge against future declines in prices of RECs or other environmental attributes. If our renewable energy facilities do not generate the amount of electricity required to earn the RECs or other environmental attributes sold under such forward contracts or if for any reason the electricity we generate does not produce RECs or other environmental attributes for a particular state, we may be required to make up the shortfall of RECs or other environmental attributes under such forward contracts through purchases on the open market or make payments of liquidated damages. We have from time to time provided guarantees of Terra LLC as credit support for these obligations. Additionally, forward contracts for REC sales


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often contain adequate assurances clauses that allow our counterparties to require us to provide credit support in the form of parent guarantees, letters of credit or cash collateral.

We are currently limited in our ability to hedge sufficient volumes of our anticipated RECs or other environmental attributes, leaving us exposed to the risk of falling prices for RECs or other environmental attributes. RECs are created through state law requirements for utilities to purchase a portion of their energy from renewable energy sources and changes in state laws or regulation relating to RECs may adversely affect the availability of RECs or other environmental attributes and the future prices for RECs or other environmental attributes, which could have an adverse effect on our business, financial condition and results of operations.

Operation of renewable energy facilities involves significant risks and hazards that could have a material adverse effect on our business, financial condition, results of operations and cash flows. We may not have adequate insurance to cover these risks and hazards.

The ongoing operation of our facilities involves risks that include the breakdown or failure of equipment or processes or performance below expected levels of output or efficiency due to wear and tear, latent defect, design error or operator error or force majeure events, among other things. Operation of our facilities also involves risks that we will be unable to transport our product to our customers in an efficient manner due to a lack of transmission capacity. Unplanned outages of generating units, including extensions of scheduled outages, occur from time to time and are an inherent risk of our business. Unplanned outages typically increase our operation and maintenance expenses and may reduce our revenues as a result of generating and selling less power or require us to incur significant costs as a result of obtaining replacement power from third parties in the open market to satisfy our forward power sales obligations.

Our inability to efficiently operate our renewable energy facilities, manage capital expenditures and costs and generate earnings and cash flow from our asset-based businesses could have a material adverse effect on our business, financial condition, results of operations and cash flows. While we maintain insurance, obtain warranties from vendors and obligate contractors to meet certain performance levels, the proceeds of such insurance, warranties or performance guarantees may not cover our lost revenues, increased expenses or liquidated damages payments should we experience equipment breakdown or non-performance by contractors or vendors.

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

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

Our business is subject to extensive federal, state and local laws in the U.S. and regulations in the foreign countries in which we operate. Compliance with the requirements under these various regulatory regimes may cause us to incur significant costs, and failure to comply with such requirements could result in the shutdown of the non-complying facility or, the imposition of liens, fines and/or civil or criminal liability.

With the exception of certain of our utility scale plants, our renewable energy facilities located in the United States in our portfolio are QFs as defined under PURPA. Depending upon the power production capacity of the facility in question, our QFs and their immediate project company owners may be entitled to various exemptions from ratemaking and certain other regulatory provisions of the FPA, from the books and records access provisions of PUHCA, and from state organizational and financial regulation of electric utilities.


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Certain of our utility scale plants and their owners are exempt wholesale generators, as defined under PURPA (each, an EWG) which exempts each EWG and us (for purposes of our ownership of each such company) from the federal books and access provisions of PUHCA. Certain of the EWGs are also QFs. EWGs and their owners are subject to regulation for most purposes as “public utilities” under the FPA, including regulation of their rates and their issuances of securities. Each of our EWGs has obtained “market based rate authorization” and associated blanket authorizations and waivers from FERC under the FPA, which allows it to sell electricity, capacity and ancillary services at wholesale at negotiated, market based rates, instead of cost-of-service rates, as well as waivers of, and blanket authorizations under, certain FERC regulations that are commonly granted to market based rate sellers, including blanket authorizations to issue securities.

The failure of our QFs to maintain QF status may result in their becoming subject to significant additional regulatory requirements. In addition, the failure of the EWGs, or our QFs to comply with applicable regulatory requirements may result in the imposition of penalties.

In particular, the EWGs, and any project companies that own or operate our QFs that obtain market based rate authority from FERC under the FPA are or will be subject to certain market behavior and anti-manipulation rules as established and enforced by FERC, and if they are determined to have violated those rules, will be subject to potential disgorgement of profits associated with the violation, penalties, and suspension or revocation of their market-based rate authority. If such entities were to lose their market-based rate authority, they would be required to obtain FERC’s acceptance of a cost-of-service rate schedule for wholesale sales of electric energy, capacity and ancillary services and could become subject to significant accounting, record-keeping, and reporting requirements that are imposed on FERC regulated public utilities with cost-based rate schedules.

Substantially all of our assets are also subject to the rules and regulations applicable to power generators generally, in particular the Reliability Standards of the North American Electric Reliability Corporation or similar standards in Canada, the United Kingdom and Chile. If we fail to comply with these mandatory Reliability Standards, we could be subject to sanctions, including substantial monetary penalties, increased compliance obligations and disconnection from the grid.

The regulatory environment for electricity generation in the United States has undergone significant changes in the last several years due to state and federal policies affecting the wholesale and retail power markets and the creation of incentives for the addition of large amounts of new renewable energy generation and demand response resources. These changes are ongoing and we cannot predict the ultimate effect that the changing regulatory environment will have on our business. In addition, in some of these markets, interested parties have proposed material market design changes, as well as made proposals to re-regulate the markets or require divestiture of power generation assets by asset owners or operators to reduce their market share. If competitive restructuring of the power markets is reversed, discontinued or delayed, our business prospects and financial results could be negatively impacted.

Laws, governmental regulations and policies supporting renewable energy, and specifically solar and wind energy (including tax incentives), could change at any time, including as a result of new political leadership, and such changes may materially adversely affect our business and our growth strategy.

Renewable energy generation assets currently benefit from, or are affected by, various federal, state and local governmental incentives and regulatory policies. In the United States, these policies include federal ITCs, PTCs, and trade import tariff policies, as well as state RPS and integrated resource plan (“IRP”) programs, state and local sales and property taxes, siting policies, grid access policies, rate design, net energy metering, and modified accelerated cost-recovery system of depreciation. The growth of our wind and solar energy business will also be dependent on the federal and state tax and regulatory regimes generally and as they relate in particular to our investments in our wind and solar facilities. For example, future growth in the renewable energy industry in the U.S. will be impacted by the availability of ITC and PTCs and accelerated depreciation and other changes to the federal income tax codes, including reductions in rates or changes that affect the ability of tax equity providers to effectively obtain the benefit of available tax credits or deductions or forecast their future tax liabilities, which may materially impair the market for tax equity financing for wind and solar power plants. Any effort to overturn federal and state laws, regulations or policies that are supportive of wind and solar power plants or that remove costs or other limitations on other types of generation that compete with wind and solar power plants could materially and adversely affect our business, financial condition, results of operations and cash flows.

Many U.S. states have adopted RPS programs mandating that a specified percentage of electricity sales come from eligible sources of renewable energy. If the RPS requirements are reduced or eliminated, it could lead to fewer future power contracts or lead to lower prices for the sale of power in future power contracts, which could have a material adverse effect on our future growth prospects. Such material adverse effects may result from decreased revenues, reduced economic returns on


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certain project company investments, increased financing costs and/or difficulty obtaining financing.

Renewable energy sources in Canada benefit from federal and provincial incentives, such as RPS programs, accelerated cost recovery deductions allowed for tax purposes, the availability of offtake agreements through RPS and the Ontario FIT program, and other commercially oriented incentives. Renewable energy sources in Chile benefit from an RPS program. Any adverse change to, or the elimination of, these incentives could have a material adverse effect on our business and our future growth prospects.

We are also subject to laws and regulations that are applicable to business entities generally, including local, state and federal tax laws. As discussed in Government Incentives and Legislation within Item 1. Business, on December 22, 2017, the U.S. government enacted the Tax Act, which contains several provisions that positively and negatively impact our business and operations. If any of the laws or governmental regulations or policies that support renewable energy change, or if we are subject to changes to other existing laws or regulations or new laws or regulation that impact our tax position, increase our compliance costs, are burdensome or otherwise negatively impact our business, such new or changed laws or regulations may have a material adverse effect on our business, financial condition, results of operations and cash flows.

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

Our facilities may require periodic upgrading and improvement. Any unexpected operational or mechanical failure, including failure associated with breakdowns and forced outages, and any decreased operational or management performance, could reduce our facilities’ generating capacity below expected levels, reducing our revenues and jeopardizing our ability to pay dividends to holders of our Class A common stock at forecasted levels or at all. Incomplete performance by us or third parties under O&M agreements may increase the risks of operational or mechanical failure of our facilities. Degradation of the performance of our renewable energy facilities provided for in the related PPAs may also reduce our revenues. Unanticipated capital expenditures associated with maintaining, upgrading or repairing our facilities may also reduce profitability.

We may also choose to refurbish or upgrade our facilities based on our assessment that such activity will provide adequate financial returns and key assumptions underpinning a decision to make such an investment may prove incorrect, including assumptions regarding construction costs, timing, available financing and future power prices. This could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Moreover, spare parts for wind turbines and solar facilities and key pieces of equipment may be hard to acquire or unavailable to us. Sources of some significant spare parts and other equipment are located outside of North America and the other jurisdictions in which we operate. If we were to experience a shortage of or inability to acquire critical spare parts we could incur significant delays in returning facilities to full operation, which could negatively impact our business financial condition, results of operations and cash flows.

Developers of renewable energy facilities depend on a limited number of suppliers of solar panels, inverters, module turbines, towers and other system components and turbines and other equipment associated with wind power plants. Any shortage, delay or component price change from these suppliers could result in construction or installation delays, which could affect the number of renewable energy facilities we are able to acquire in the future.

There have been periods of industry-wide shortage of key components, including solar panels and wind turbines, in times of rapid industry growth. The manufacturing infrastructure for some of these components has a long lead time, requires significant capital investment and relies on the continued availability of key commodity materials, potentially resulting in an inability to meet demand for these components. In addition, the United States government has imposed tariffs on imported solar cells and modules. The tariff begins at 30% in 2018 and declines to 25%, 20% and 15% in 2019, 2020 and 2021, respectively. The first 2.5 gigawatts of imported solar cells are exempted from these tariffs. If project developers purchase solar panels containing cells manufactured in China, our purchase price for renewable energy facilities may reflect the tariff penalties mentioned above. A shortage of key commodity materials could also lead to a reduction in the number of renewable energy facilities that we may have the opportunity to acquire in the future, or delay or increase the costs of acquisitions.

We may incur unexpected expenses if the suppliers of components in our renewable energy facilities default in their warranty obligations.

The solar panels, inverters, modules and other system components utilized in our solar generation facilities are generally covered by manufacturers’ warranties, which typically range from 5 to 20 years. When purchasing wind turbines, the purchaser will enter into warranty agreements with the manufacturer which typically expire within two to five years after the


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turbine delivery date. In the event any such components fail to operate as required, we may be able to make a claim against the applicable warranty to cover all or a portion of the expense associated with the faulty component. However, these suppliers could cease operations and no longer honor the warranties, which would leave us to cover the expense associated with the faulty component. For example, a portion of our solar power plants utilize modules made by SunEdison and certain of its affiliates that were debtors in the SunEdison Bankruptcy. Our business, financial condition, results of operations and cash flows could be materially adversely affected if we cannot make claims under warranties covering our renewable energy facilities.

We are subject to environmental, health and safety laws and regulations and related compliance expenditures and liabilities.

Our assets are subject to numerous and significant federal, state, local and foreign laws, and other requirements governing or relating to the environment. Our facilities could experience incidents, malfunctions and other unplanned events, such as spills of hazardous materials that may result in personal injury, penalties and property damage. In addition, certain environmental laws may result in liability, regardless of fault, concerning contamination at a range of properties, including properties currently or formerly owned, leased or operated by us and properties where we disposed of, or arranged for disposal of, waste and other hazardous materials. As such, the operation of our facilities carries an inherent risk of environmental liabilities, and may result in our involvement from time to time in administrative and judicial proceedings relating to such matters. While we have implemented environmental management programs designed to continually improve environmental, health and safety performance, we cannot assure you that such liabilities including significant required capital expenditures, as well as the costs for complying with environmental laws and regulations, will not have a material adverse effect on our business, financial condition, results of operations and cash flows.

Harming of protected species can result in curtailment of wind power plant operations, monetary fines and negative publicity.

The operation of wind power plants can adversely affect endangered, threatened or otherwise protected animal species. Wind power plants, in particular, involve a risk that protected species will be harmed, as the turbine blades travel at a high rate of speed and may strike flying animals (such as birds or bats) that happen to travel into the path of spinning blades.

Our wind power plants are known to strike and kill flying animals, and occasionally strike and kill endangered or protected species, including protected golden or bald eagles. As a result, we expect to observe all industry guidelines and governmentally recommended best practices to avoid harm to protected species, such as avoiding structures with perches, avoiding guy wires that may kill birds or bats in flight, or avoiding lighting that may attract protected species at night. In addition, we will attempt to reduce the attractiveness of a site to predatory birds by site maintenance (e.g., mowing, removal of animal and bird carcasses, etc.).

Where possible, we will obtain permits for incidental taking of protected species. We hold such permits for some of our wind power plants, particularly in Hawaii, where several species are endangered and protected by law. We are monitoring the U.S. Fish & Wildlife Service (“USF&WS”) rulemaking and policy about obtaining incidental take permits for bald and golden eagles at locations with low to moderate risk of such events and will seek permits as appropriate. We are also in the process of amending the incidental take permits for certain wind power plants in Hawaii, where observed endangered species mortality has exceeded prior estimates and may exceed permit limits on such takings.

Excessive taking of protected species could result in requirements to implement mitigation strategies, including curtailment of operations, and/or substantial monetary fines and negative publicity. Our wind power plants in Hawaii, several of which hold incidental take permits to authorize the incidental taking of small numbers of protected species, are subject to curtailment (i.e., reduction in operations) if excessive taking of protected species is detected through monitoring. At some of the facilities in Hawaii, curtailment has been implemented, but not at levels that materially reduce electricity generation or revenues. Such curtailments (to protect bats) have reduced nighttime operation and limited operation to times when wind speeds are high enough to prevent bats from flying into a wind power plant’s blades. Based on continuing concerns about species other than bats, however, additional curtailments are possible at those locations. We cannot guarantee that such curtailments, any monetary fines that are levied or negative publicity that we receive as a result of incidental taking of protected species will not have a material adverse effect on our business, financial condition, results of operations and cash flows.

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

Our renewable energy facilities, or those that we otherwise acquire in the future, may be targets of terrorist activities that could cause environmental repercussions and/or result in full or partial disruption of the facilities’ ability to generate


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electricity. Hostile cyber intrusions, including those targeting information systems as well as electronic control systems used at the facilities and for the related distribution systems, could severely disrupt business operations and result in loss of service to customers, as well as create significant expense to repair security breaches or system damage.

Furthermore, certain of our renewable energy facilities are located in active earthquake zones. The occurrence of a natural disaster, such as an earthquake, hurricane, lightning, flood or localized extended outages of critical utilities or transportation systems, or any critical resource shortages, affecting us could cause a significant interruption in our business, damage or destroy our facilities or those of our suppliers or the manufacturing equipment or inventory of our suppliers.

Additionally, certain of our renewable energy facilities and equipment are at risk for theft and damage. For example, we are at risk for copper wire theft, especially at our solar generation facilities, due to an increased demand for copper in the United States and internationally. Theft of copper wire or solar panels can cause significant disruption to our operations for a period of months and can lead to operating losses at those locations. Damage to wind turbine equipment may also occur, either through natural events such as lightning strikes that damage blades or in-ground electrical systems used to collect electricity from turbines, or through vandalism, such as gunshots into towers or other generating equipment. Such damage can cause disruption of operations for unspecified periods which may lead to operating losses at those locations.

Any such terrorist acts, environmental repercussions or disruptions, natural disasters or theft incidents could result in a significant decrease in revenues or significant reconstruction, remediation or replacement costs, beyond what could be recovered through insurance policies, which could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Any cyber-attack or other failure of the Company’s communications and technology infrastructure and systems could have an adverse impact on the Company.

The Company relies on the secure storage, processing and transmission of electronic data and other information and technology systems, including software and hardware, for the efficient operation of its renewable energy facilities. If the Company, its communications systems or computer hardware or software are impacted by a cyber-attack or cyber-intrusion, particularly or as part of a broader attack or intrusion by third parties, including computer hackers, foreign governments and cyber terrorists, the Company’s operations or capabilities could be interrupted or diminished and important information could be lost, deleted or stolen, which could have a negative impact on the Company’s revenues and results of operations or which could cause the Company to incur unanticipated liabilities or costs and expenses to replace or enhance affected systems, including costs related to cyber security for the Company’s renewable energy facilities.

Our use and enjoyment of real property rights for our renewable energy facilities may be adversely affected by the rights of lienholders and leaseholders that are superior to those of the grantors of those real property rights to us.

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

International operations subject us to political and economic uncertainties.

Our portfolio consists of renewable energy facilities located in the United States (including Puerto Rico), Canada, the United Kingdom and Chile. If we consummate the Tender Offer for the shares of Saeta Yield, we will also operate in Spain, Portugal and Uruguay. In addition, we could decide to expand our presence in our existing international markets or further our expansion into new international markets. As a result, our activities are and will be subject to significant political and economic uncertainties that may adversely affect our operating and financial performance. These uncertainties include, but are not limited to:

the risk of a change in renewable power pricing policies, possibly with retroactive effect;
political and economic instability;
measures restricting the ability of our facilities to access the grid to deliver electricity at certain times or at all;


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the macroeconomic climate and levels of energy consumption in the countries where we have operations;
the comparative cost of other sources of energy;
changes in taxation policies and/or the regulatory environment in the countries in which we have operations, including reductions to renewable power incentive programs;
the imposition of currency controls and foreign exchange rate fluctuations;
high rates of inflation;
protectionist and other adverse public policies, including local content requirements, import/export tariffs, increased regulations or capital investment requirements;
changes to land use regulations and permitting requirements;
risk of nationalization or other expropriation of private enterprises and land, including creeping regulation that reduces the value of our facilities or governmental incentives associated with renewable energy;
difficulty in timely identifying, attracting and retaining qualified technical and other personnel;
difficulty competing against competitors who may have greater financial resources and/or a more effective or established localized business presence;
difficulties with, and extra-normal costs of, recruiting and retaining local individuals skilled in international business operations;
difficulty in developing any necessary partnerships with local businesses on commercially acceptable terms; and
being subject to the jurisdiction of courts other than those of the United States, which courts may be less favorable to us.

These uncertainties, many of which are beyond our control, could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Our international operations require us to comply with anti-corruption laws and regulations of the United States government and various non-U.S. jurisdictions.

Doing business in multiple countries requires us and our subsidiaries to comply with the laws and regulations of the United States government and various non-U.S. jurisdictions. Our failure to comply with these rules and regulations may expose us to liabilities. These laws and regulations may apply to us, our subsidiaries, individual directors, officers, employees and agents, and may restrict our operations, trade practices, investment decisions and partnering activities. In particular, our non-U.S. operations are subject to United States and foreign anti-corruption laws and regulations, such as the Foreign Corrupt Practices Act of 1977, as amended (“FCPA”). The FCPA prohibits United States companies and their officers, directors, employees and agents acting on their behalf from corruptly offering, promising, authorizing or providing anything of value to foreign officials for the purposes of influencing official decisions or obtaining or retaining business or otherwise obtaining favorable treatment. The FCPA also requires companies to make and keep books, records and accounts that accurately and fairly reflect transactions and dispositions of assets and to maintain a system of adequate internal accounting controls. As part of our business, we deal with state-owned business enterprises, the employees and representatives of which may be considered foreign officials for purposes of the FCPA. As a result, business dealings between our employees and any such foreign official could expose the Company to the risk of violating anti-corruption laws even if such business practices may be customary or are not otherwise prohibited between the Company and a private third party. Violations of these legal requirements are punishable by criminal fines and imprisonment, civil penalties, disgorgement of profits, injunctions, debarment from government contracts as well as other remedial measures. We have established policies and procedures designed to assist us and our personnel in complying with applicable United States and non-U.S. laws and regulations; however, we cannot assure you that these policies and procedures will completely eliminate the risk of a violation of these legal requirements, and any such violation (inadvertent or otherwise) could have a material adverse effect on our business, financial condition and results of operations.

In the future, we may acquire certain assets in which we have limited control over management decisions and our interests in such assets may be subject to transfer or other related restrictions.

We have acquired, and may seek to acquire, assets in the future in which we own less than a majority of the related interests in the assets. In these investments, we will seek to exert a degree of influence with respect to the management and operation of assets in which we own less than a majority of the interests by negotiating to obtain positions on management committees or to receive certain limited governance rights, such as rights to veto significant actions. However, we may not


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always succeed in such negotiations, and we may be dependent on our co-venturers to operate such assets. Our co-venturers may not have the level of experience, technical expertise, human resources management and other attributes necessary to operate these assets optimally. In addition, conflicts of interest may arise in the future between us and our stockholders, on the one hand, and our co-venturers, on the other hand, where our co-venturers’ business interests are inconsistent with our interests and those of our stockholders. Further, disagreements or disputes between us and our co-venturers could result in litigation, which could increase our expenses and potentially limit the time and effort our officers and directors are able to devote to our business.

The approval of co-venturers also may be required for us to receive distributions of funds from assets or to sell, pledge, transfer, assign or otherwise convey our interest in such assets. Alternatively, our co-venturers may have rights of first refusal or rights of first offer in the event of a proposed sale or transfer of our interests in such assets. These restrictions may limit the price or interest level for our interests in such assets, in the event we want to sell such interests.

Negative public or community response to renewable energy facilities could adversely affect our acquisition of new facilities and the operation of our existing facilities.

Negative public or community response to solar, wind and other renewable energy facilities, could adversely affect our ability to acquire and operate our facilities. Our experience is that such opposition subsides over time after renewable energy facilities are completed and are operating, but there are cases where opposition, disputes and even litigation continue into the operating period and could lead to curtailment of a facility or other facility modifications.

The seasonality of our operations may affect our liquidity.

We will need to maintain sufficient financial liquidity to absorb the impact of seasonal variations in energy production or other significant events. Our principal sources of liquidity are cash generated from our operating activities, the cash retained by us for working capital purposes out of the gross proceeds of financing activities as well as our borrowing capacity under our existing credit facilities, subject to any conditions required to draw under such existing credit facilities. Our quarterly results of operations may fluctuate significantly for various reasons, mostly related to economic incentives and weather patterns.

For instance, the amount of electricity and revenues generated by our solar generation facilities is dependent in part on the amount of sunlight, or irradiation, where the assets are located. Due to shorter daylight hours in winter months which results in less irradiation, the generation produced by these facilities will vary depending on the season. The electricity produced and revenues generated by a wind power plant depend heavily on wind conditions, which are variable and difficult to predict. Operating results for wind power plants vary significantly from period to period depending on the wind conditions during the periods in question. Additionally, to the extent more of our renewable energy facilities are located in the northern or southern hemisphere, overall generation of our entire asset portfolio could be impacted by seasonality. Further, time-of-day pricing factors vary seasonally which contributes to variability of revenues. We expect our portfolio of renewable energy facilities to generate the lowest amount of electricity during the first and fourth quarters. However, we expect aggregate seasonal variability to decrease if geographic diversity of our portfolio between the northern and southern hemisphere increases.

If we fail to adequately manage the fluctuations in the timing of distributions from our renewable energy facilities, our business, financial condition or results of operations could be materially affected. The seasonality of our energy production may create increased demands on our working capital reserves and borrowing capacity under our existing credit facilities during periods where cash generated from operating activities are lower. In the event that our working capital reserves and borrowing capacity under our existing credit facilities are insufficient to meet our financial requirements, or in the event that the restrictive covenants in our existing credit facilities restrict our access to such facilities, we may require additional equity or debt financing to maintain our solvency. Additional equity or debt financing may not be available when required or available on commercially favorable terms or on terms that are otherwise satisfactory to us, in which event our financial condition may be materially adversely affected.

The Merger and Sponsorship Transaction may result in significant employee departures, including turnover of our executive officers and members of our senior management.

In connection with the expected relocation of the headquarters of the Company to New York, New York, we expect to experience departures of a significant number of employees. In addition, we have experienced changes to our executive officers and senior management, including the departure of our interim Chief Executive Officer, Chief Financial Officer and General Counsel upon the closing of the Sponsorship Transaction. The governance agreements entered into between the Company and Brookfield in connection with the Merger and Sponsorship Transaction provide for Brookfield to appoint our Chief Executive Officer, Chief Financial Officer and General Counsel, and Brookfield will directly set the compensation of these officers.


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We have incurred substantial indebtedness and may in the future incur additional substantial indebtedness, which may limit our ability to grow our business, reduce our financial flexibility and otherwise may have a material negative impact on our business, results of operations and financial condition.

We have incurred substantial corporate and project-level indebtedness and may incur additional substantial indebtedness in the future. This substantial indebtedness has certain consequences on our business, results of operations and financial condition, including, but not limited to, the following:

increasing our vulnerability to, and reducing our flexibility to, respond to general adverse economic and industry conditions;
limiting our flexibility in planning for, or reacting to, changes in our business and the competitive environment and business in which we operate;
limiting our ability to borrow additional amounts to fund the growth of the Company or otherwise meet our obligations;
requiring us to dedicate a significant portion of our revenues to pay the principal of and interest on our indebtedness; and
magnifying the impact of fluctuations in our cash flows on cash available for the payment of dividends to the holders of our Class A common stock.

As a result of these consequences, our substantial indebtedness could have a material adverse effect on our business, results of operations and financial condition.

We are subject to operating and financial restrictions through covenants in our corporate loan, debt and security agreements that may limit our operational activities or limit our ability to raise additional indebtedness.

We are subject to operating and financial restrictions through covenants in our loan, debt and security agreements. These restrictions prohibit or limit our ability to, among other things, incur additional debt, provide guarantees for indebtedness, grant liens, dispose of assets, liquidate, dissolve, amalgamate, consolidate or effect corporate or capital reorganizations, and declare distributions. A financial covenant in our corporate revolver limits the overall corporate indebtedness that we may incur to a multiple of our cash available for distribution, which may limit our ability to obtain additional financing, withstand downturns in our business and take advantage of business and development opportunities. If we breach our covenants, our corporate revolving credit facility, term loan facility or senior notes may be terminated or come due and such event may cause our credit rating to deteriorate and subject us to higher interest and financing costs. We may also be required to seek additional debt financing on terms that include more restrictive covenants, require repayment on an accelerated schedule or impose other obligations that limit our ability to grow our business, acquire needed assets or take other actions that we might otherwise consider appropriate or desirable.

Changes in our credit ratings may have an adverse effect on our financial position and ability to raise capital.

The credit rating assigned to the Company or any of our subsidiaries’ debt securities may be changed or withdrawn entirely by the relevant rating agency. A lowering or withdrawal of such ratings may have an adverse effect on our financial position and ability to raise capital.

If we are deemed to be an investment company, we may be required to institute burdensome compliance requirements and our activities may be restricted, which may make it difficult for us to complete strategic acquisitions or affect combinations.

If we are deemed to be an investment company under the Investment Company Act of 1940 (the “Investment Company Act”) our business would be subject to applicable restrictions under the Investment Company Act, which could make it impractical for us to continue our business as contemplated. We believe our company is not an investment company under Section 3(b)(1) of the Investment Company Act because we are primarily engaged in a non-investment company business, and we intend to conduct our operations so that we will not be deemed an investment company. However, if we were to be deemed an investment company, restrictions imposed by the Investment Company Act, including limitations on our capital structure and our ability to transact with affiliates, could make it impractical for us to continue our business as contemplated.



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Risks Related to Our Tender Offer for the Common Shares of Saeta Yield

The Tender Offer is subject to limited conditions, which may not be satisfied on a timely basis or at all and we may be required to accept conditions, obligations, undertakings or remedies imposed by the European Commission which may limit our ability to realize the expected benefits of the Tender Offer.

As discussed in Item 1. Business above, on February 7, 2018, we announced our plan to launch the Tender Offer for the outstanding shares of Saeta Yield. Under the irrevocable undertaking agreements, TERP Spanish HoldCo agreed to offer 12.20 Euros per share for the outstanding shares of Saeta Yield subject only to obtaining merger control clearance from the European Commission (to the extent such clearance is legally required) and Cobra and GIP irrevocably accepting the Tender Offer in respect of their shares representing no less than 48.222% of Saeta Yield’s voting share capital. If these conditions are not satisfied on a timely basis or at all, we would not be able to complete the Tender Offer in accordance with our business plans or at all, which could have an adverse impact on our business and the market value of our Class A common stock. Moreover, pursuant to the irrevocable undertaking agreements, TERP Spanish HoldCo has agreed to accept any conditions, obligations, undertakings or remedies that may be imposed by the European Commission or other antitrust authority other than any conditions, obligations, undertaking or remedy that requires an action by any person or entity other than the Company and Saeta Yield and its subsidiaries. Any such condition, obligation, undertaking or remedy may adversely impact the Company or may limit the Company’s ability to realize any expected benefits of the Tender Offer.

We may not be able to execute on our funding plan for the Tender Offer on attractive terms or at all.

Under the irrevocable undertaking agreements, we are required to make the Tender Offer to all shareholders of Saeta Yield subject to certain limited exceptions. The Tender Offer is not subject to a financing condition. The aggregate purchase price of the shares subject to the irrevocable undertaking agreements is approximately $600 million, and, if 100% of the remaining shares of Saeta Yield are tendered in connection with the Tender Offer, the aggregate purchase price of the shares (including the shares subject to the irrevocable undertaking agreements) is approximately $1.2 billion. Assuming all of the common shares of Saeta Yield are tendered, we plan to fund the purchase price of the tendered shares using a combination of an equity issuance of our common stock and existing corporate liquidity, including borrowings under the Sponsor Line Agreement and the New Revolver (as defined and discussed in Liquidity and Capital Resources within Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations). We expect to repay these borrowings using a combination of sources, including new non-recourse financings of our existing unencumbered wind and solar assets and certain cash released from the Saeta Yield assets.

If we are not able to issue common stock, or access our available liquidity as we expect, or are otherwise unable to execute on our funding plan as we expect, we would continue to be obligated to complete the Tender Offer subject to the two conditions described above. We may decide to alter our funding plan to issue more or less equity and use more or less of our existing corporate liquidity. A failure to successfully execute on our funding plan for the Tender Offer could have a material negative impact on the market price of our common stock and our results of operations.

In connection with the Tender Offer, we entered into the Letter of Credit Facilities pursuant to which two banks posted the Bank Guarantee to secure the obligations of TERP Spanish HoldCo to complete the Tender Offer. If we do not have the funding necessary to complete the Tender Offer, the Bank Guarantee held by the CNMV may be drawn and we would have an obligation to reimburse the banks. In addition, if any amount is drawn under the Bank Guarantee, or if an event of default occurs under the Letter of Credit Facilities, we may be required to cash collateralize the entire amount of the Bank Guarantee that has not been drawn. Under the terms of the Letter of Credit Facilities, we are required to maintain minimum liquidity requirements of $500.0 million under the Sponsor Line Agreement and $400.0 million under the New Revolver. These minimum liquidity requirements may limit our ability to pursue or fund other acquisitions or growth capital expenditures.

We may not realize the expected benefits of the acquisition of Saeta Yield.

Our underwriting of the Tender Offer included certain assumptions, including, but not limited to, assumptions related to our ability to integrate Saeta Yield into our business operations, the performance of Saeta Yield’s wind and solar assets, the effect of regulation in Spain, Portugal and Uruguay, the realization of costs savings in connection with taking Saeta Yield private, and our plan to finance the Saeta Yield transaction, including the costs and effects of that financing plan on our capital structure. Even though we believe the Tender Offer will be accretive to cash available for distribution to our shareholders on a per share basis, the Saeta Yield acquisition could result in less accretion than we expect or could result in dilution to cash available for distribution to our shareholders as a result of incorrect assumptions in our evaluation of the Saeta Yield transaction, unforeseen consequences or external events beyond our control, which could have an adverse impact on the trading price of our common stock and our business and results of operations.


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The wind and solar assets of Saeta Yield in Spain are subject to significant government regulation that has the effect of regulating the return of renewable energy facilities in the country, and any reduction in the regulated return to rates lower than we expect could have a material negative impact on the results of our operations.

The wind and solar assets of Saeta Yield are located primarily in Spain with additional assets located in Portugal and Uruguay. The wind and solar assets located in Spain are subject to regulated rates of return that are subject to revision every six years, with the next revision expected to occur in 2020. This regulation allows the Spanish government to revise the rate of return for renewable energy facilities to set a reasonable rate of return. Although our underwriting assumptions have incorporated a downward revision to the regulated rate of return that renewable energy facilities in Spain are permitted to earn, if the regulated return is revised to a level lower than we expect, then the revenues that we earn from the assets of Saeta Yield would be lower than we expect, which could have a material negative impact on the results of our operations of those assets.

If less than 90% of the outstanding shares of Saeta Yield are tendered in connection with the Tender Offer, we may decide to launch a delisting offer in order to take Saeta Yield private, which would result in a fair price review by Spanish regulators and could result in a higher tender offer price.

Under Spanish law, if 90% of the shares are tendered and accepted, we will be able to invoke procedures to purchase the remaining un-tendered shares of Saeta Yield at the offer price, which would result in us acquiring 100% of the shares of Saeta Yield and would result in a delisting of Saeta Yield. If less than 90% of the Saeta Yield shares are tendered pursuant to our voluntary Tender Offer, we may launch a delisting offer under Spanish law. This delisting offer would be subject to a fair price review by the CNMV, which could result in an increase in the offer price to the remaining shareholders. If less than 90% of the shares of Saeta Yield are tendered, Spanish law would subject governance of Saeta Yield to certain minority protections, including proportionate board representation for minority shareholders and certain protections regarding related party transactions.

Risks Related to our Growth Strategy

The growth of our business depends on locating and acquiring interests in attractive renewable energy facilities at favorable prices and with favorable financing terms. Additionally, even if we consummate such acquisitions and financings on terms that we believe are favorable, such acquisitions may in fact result in a decrease in cash available for distribution per Class A common share.

The following factors, among others, could affect the availability of attractive renewable energy facilities to grow our business and dividend per Class A common share:

competing bids for a renewable energy facility, including from companies that may have substantially greater capital and other resources than we do;
fewer third party acquisition opportunities than we expect, which could result from, among other things, available renewable energy facilities having less desirable economic returns or higher risk profiles than we believe suitable for our business plan and investment strategy;
risk relating to our ability to successfully acquire projects from the ROFO portfolio pursuant to the Merger and Sponsorship Transaction with Brookfield; and
our access to the capital markets for equity and debt (including project-level debt) at a cost and on terms that would be accretive to our shareholders.

Even if we consummate acquisitions that we believe will be accretive to our dividends per share, those acquisitions may in fact result in a decrease in dividends per share as a result of incorrect assumptions in our evaluation of such acquisitions, unforeseen consequences or external events beyond our control.

Our acquisition strategy exposes us to substantial risk.

Our acquisition of renewable energy facilities or of companies that own and operate renewable energy facilities, such as Saeta Yield, is subject to substantial risk, including the failure to identify material problems during due diligence (for which we may not be indemnified post-closing), the risk of over-paying for assets (or not making acquisitions on an accretive basis), the ability to obtain or retain customers and, if the renewable energy facilities are in new markets, the risks of entering markets where we have limited experience. While we perform due diligence on prospective acquisitions, we may not be able to discover


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all potential operational deficiencies in such renewable energy facilities. In addition, our expectations for the operating performance of newly constructed renewable energy facilities as well as those under construction are based on assumptions and estimates made without the benefit of operating history. However, the ability of these renewable energy facilities to meet our performance expectations is subject to the risks inherent in newly constructed renewable energy facilities and the construction of such facilities, including, but not limited to, degradation of equipment in excess of our expectations, system failures and outages. Future acquisitions may not perform as expected or the returns from such acquisitions may not support the financing utilized to acquire them or maintain them. Furthermore, integration and consolidation of acquisitions requires substantial human, financial and other resources and may divert management’s attention from our existing business concerns, disrupt our ongoing business or not be successfully integrated. As a result, the consummation of acquisitions may have a material adverse effect on our business, financial condition, results of operations and cash flows.

We may not be able to effectively identify or consummate any future acquisitions. Additionally, even if we consummate acquisitions, such acquisitions may in fact result in a decrease in cash available for distribution to holders of our Class A common stock. In addition, we may engage in asset dispositions or other transactions that result in a decrease in our cash available for distribution.

Future acquisition opportunities for renewable energy facilities are limited and there is substantial competition for the acquisition of these assets. Moreover, while Brookfield and its affiliates will grant us a right of first offer with respect to the projects in the right of first offer portfolio as a result of the Merger and Sponsorship Transaction, there is no assurance that we will be able to acquire or successfully integrate any such projects. We will compete with other companies for future acquisition opportunities from Brookfield and its affiliates and third parties.

Competition for acquisitions may increase our cost of making acquisitions or cause us to refrain from making acquisitions at all. Some of our competitors are much larger than us with substantially greater resources. These companies may be able to pay more for acquisitions and may be able to identify, evaluate, bid for and purchase a greater number of assets than our resources permit. If we are unable to identify and consummate future acquisitions, it will impede our ability to execute our growth strategy and limit our ability to increase the amount of dividends paid to holders of our Class A common stock. In addition, as we continue to manage our liquidity profile, we may engage in asset dispositions, or incur additional project-level debt, which may result in a decrease in our cash available for distribution.

Even if we consummate acquisitions that we believe will be accretive to such cash per unit, those acquisitions may in fact result in a decrease in such cash per unit as a result of incorrect assumptions in our evaluation of such acquisitions, unforeseen consequences or other external events beyond our control. Furthermore, if we consummate any future acquisitions, our capitalization and results of operations may change significantly, and stockholders will generally not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in determining the application of these funds and other resources.

Our ability to grow and make acquisitions with cash on hand may be limited by our cash dividend policy.

In the future, we intend to pay dividends to our shareholders each quarter and to rely primarily upon external financing sources, including the issuance of debt and equity securities to fund our acquisitions and growth capital expenditures. We may be precluded from pursuing otherwise attractive acquisitions if the projected short-term cash flow from the acquisition or investment is not adequate to service the capital raised to fund the acquisition or investment. As such, our growth may not be as fast as that of businesses that reinvest their available cash to expand ongoing operations.

We may not have access to all operating wind and solar acquisitions that Brookfield identifies.

Our ability to grow through acquisitions depends on Brookfield’s ability to identify and present us with acquisition opportunities. Brookfield has designated the Company, subject to certain exceptions, as its primary vehicle to acquire operating wind and solar assets in North America and Western Europe. However, Brookfield has no obligation to source acquisition opportunities specifically for us. There are a number of factors which could materially and adversely impact the extent to which suitable acquisition opportunities are made available to the Company by Brookfield, for example:

It is an integral part of Brookfield’s strategy to pursue the acquisition or development of renewable power assets through consortium arrangements with institutional investors, strategic partners or financial sponsors and to form partnerships to pursue acquisitions on a specialized basis. In certain circumstances, acquisitions of operating wind and solar assets in the Company’s primary jurisdictions may be made by other Brookfield vehicles, either with or instead of the Company.


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The same professionals within Brookfield’s organization that are involved in acquisitions that are suitable for us are often responsible for the consortiums and partnerships referred to above, as well as having other responsibilities within Brookfield’s broader asset management business. Limits on the availability of such individuals will likewise result in a limitation on the availability of acquisition opportunities for us.
Brookfield will only recommend acquisition opportunities that it believes are suitable for us. The question of whether a particular acquisition is suitable is highly subjective and is dependent on a number of factors including an assessment by Brookfield of our liquidity position, the risk and return profile of the opportunity, and other factors. If Brookfield determines that an opportunity is not suitable for us, it may still pursue such opportunity on its own behalf, or on behalf of a Brookfield-sponsored vehicle.   

Our ability to raise additional capital to fund our operations and growth may be limited.

We may need to arrange additional financing to fund all or a portion of the cost of acquisitions, including our Tender Offer for the shares of Saeta Yield, potential contingent liabilities and other aspects of our operations. Our ability to arrange additional financing or otherwise access the debt or equity capital markets, either at the corporate-level or at a non-recourse project-level subsidiary, may be limited. Any limitations on our ability to obtain financing may have an adverse effect on our business, or growth prospects or our results of operations. Additional financing, including the costs of such financing, will be dependent on numerous factors, including:

general economic and capital market conditions, including the then-prevailing interest rate environment;
credit availability from banks and other financial institutions;
investor confidence in us, our partners, our Sponsor, and the regional wholesale power markets;
our financial performance and the financial performance of our subsidiaries;
our level of indebtedness and compliance with covenants in debt agreements;
our ability to file SEC reports on a timely basis and obtain audited project-level financial statements;
maintenance of acceptable credit ratings or credit quality, including maintenance of the legal and tax structure of the project-level subsidiary upon which the credit ratings may depend;
our cash flows; and
provisions of tax and securities laws that may impact raising capital.

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

Risks Inherent in an Investment in TerraForm Power, Inc.

We may not be able to pay cash dividends to holders of our Class A common stock in the future.

The amount of our cash available for distribution principally depends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things:

our ability to realize the expected benefits from Brookfield's sponsorship on our business and results of operations;
any adverse consequences arising out of our separation from SunEdison and of the SunEdison Bankruptcy;
the timing of our ability to complete our audited corporate and project-level financial statements;
risks related to our ability to file our annual and quarterly reports with the SEC on a timely basis and to satisfy the requirements of the NASDAQ Global Select Market;
our ability to integrate acquired assets and realize the anticipated benefits of these acquired assets;
counterparties’ to our offtake agreements willingness and ability to fulfill their obligations under such agreements;
price fluctuations, termination provisions and buyout provisions related to our offtake agreements;


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our ability to enter into contracts to sell power on acceptable terms as our offtake agreements expire;
delays or unexpected costs during the completion of construction of certain renewable energy facilities we intend to acquire;
our ability to successfully identify, evaluate and consummate acquisitions;
government regulation, including compliance with regulatory and permit requirements and changes in market rules, rates, tariffs and environmental laws;
operating and financial restrictions placed on us and our subsidiaries related to agreements governing our indebtedness and other agreements of certain of our subsidiaries and project-level subsidiaries generally;
our ability to borrow additional funds and access capital markets, as well as our substantial indebtedness and the possibility that we may incur additional indebtedness going forward;
our ability to compete against traditional and renewable energy companies;
hazards customary to the power production industry and power generation operations such as unusual weather conditions, catastrophic weather-related or other damage to facilities, unscheduled generation outages, maintenance or repairs, interconnection problems or other developments, environmental incidents, or electric transmission constraints and the possibility that we may not have adequate insurance to cover losses as a result of such hazards;
our ability to expand into new business segments or new geographies;
seasonal variations in the amount of electricity our wind and solar plants produce, and fluctuations in wind and solar resource conditions; and
our ability to operate our businesses efficiently, manage capital expenditures and costs tightly, manage litigation, manage risks related to international operations and generate earnings and cash flow from our asset-based businesses in relation to our debt and other obligations.

As a result of all these factors, we cannot guarantee that we will have sufficient cash generated from operations to pay a specific level of cash dividends to holders of our Class A common stock. Furthermore, holders of our Class A common stock should be aware that the amount of cash available for distribution depends primarily on our cash flow, and is not solely a function of profitability, which is affected by non-cash items. We may incur other expenses or liabilities during a period that could significantly reduce or eliminate our cash available for distribution and, in turn, impair our ability to pay dividends to holders of our Class A common stock during the period. We are a holding company and our ability to pay dividends on our Class A common stock is limited by restrictions on the ability of our subsidiaries to pay dividends or make other distributions to us, including restrictions under the terms of the agreements governing project-level financing. Our project-level financing agreements prohibit distributions to us unless certain specific conditions are met, including the satisfaction of financial ratios and the absence of payment or covenant defaults.

Furthermore, we expect to issue additional equity securities in connection with our Tender Offer for the outstanding shares of Saeta Yield, and we may issue additional equity securities in connection with any other acquisitions or growth capital expenditures. The payment of dividends on these additional equity securities may increase the risk that we will be unable to maintain or increase our per share dividend. There are no limitations in our amended and restated certificate of incorporation (other than a specified number of authorized shares) on our ability to issue equity securities, including securities ranking senior to our Class A common stock. The incurrence of bank borrowings or other debt by Terra Operating LLC or by our project-level subsidiaries to finance our growth strategy will result in increased interest expense and the imposition of additional or more restrictive covenants which, in turn, may impact the cash distributions we distribute to holders of our Class A common stock.

Finally, dividends to holders of our Class A common stock will be paid at the discretion of our Board.

Certain of our shareholders have accumulated large concentrations of holdings of our Class A shares, which among other things, may impact the liquidity of our Class A shares.

In addition to Brookfield, certain of our shareholders hold large positions in our Class A shares and new or existing shareholders may accumulate large positions in our Class A shares, which may impact the liquidity of shares of our Class A shares. In the event that shareholders hold these large positions in shares of our Class A common stock not owned by Brookfield this concentration of ownership may reduce the liquidity of our Class A common stock and may also have the effect of delaying or preventing a future change in control of our company or discouraging others from making tender offers for our shares, which could depress the price per share a bidder might otherwise be willing to pay.



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We are a holding company and our only material asset is our interest in Terra LLC, and we are accordingly dependent upon distributions from Terra LLC and its subsidiaries to pay dividends and taxes and other expenses.

TerraForm Power is a holding company and has no material assets other than its ownership of membership interests in Terra LLC, a holding company that has no material assets other than its interest in Terra Operating LLC, whose sole material assets are interests in holding companies that directly or indirectly own the renewable energy facilities that comprise our portfolio and the renewable energy facilities that we subsequently acquire. TerraForm Power, Terra LLC and Terra Operating LLC have no independent means of generating revenue. We intend to cause Terra Operating LLC’s subsidiaries to make distributions to Terra Operating LLC and, in turn, make distributions to Terra LLC, and, Terra LLC, in turn, to make distributions to TerraForm Power in an amount sufficient to cover all applicable taxes payable and dividends, if any, declared by us. To the extent that we need funds to pay a quarterly cash dividend to holders of our Class A common stock or otherwise, and Terra Operating LLC or Terra LLC is restricted from making such distributions under applicable law or regulation or is otherwise unable to provide such funds (including as a result of Terra Operating LLC’s operating subsidiaries being unable to make distributions, such as due to defaults in project-level financing agreements), it could materially adversely affect our liquidity and financial condition and limit our ability to pay dividends to holders of our Class A common stock.

Market interest rates may have an effect on the value of our Class A common stock.

One of the factors that influences the price of shares of our Class A common stock will be the effective dividend yield of such shares (i.e., the yield as a percentage of the then market price of our shares) relative to market interest rates. An increase in market interest rates may lead prospective purchasers of shares of our Class A common stock to expect a higher dividend yield. If market interest rates increase and we are unable to increase our dividend in response, including due to an increase in borrowing costs, insufficient cash available for distribution or otherwise, investors may seek alternative investments with higher yield, which would result in selling pressure on, and a decrease in the market price of, our Class A common stock. As a result, the price of our Class A common stock may decrease as market interest rates increase.

The market price and marketability of our shares may from time to time be significantly affected by numerous factors beyond our control, which may adversely affect our ability to raise capital through future equity financings.

The market price of our shares may fluctuate significantly. Many factors may significantly affect the market price and marketability of our shares and may adversely affect our ability to raise capital through equity financings and otherwise materially adversely impact our business. These factors include, but are not limited to, the following:

price and volume fluctuations in the stock markets generally;
significant volatility in the market price and trading volume of securities of registered investment companies, business development companies or companies in our sectors, which may not be related to the operating performance of these companies;
changes in our earnings or variations in operating results;
changes in regulatory policies or tax law;
operating performance of companies comparable to us; and
loss of funding sources or the ability to finance or refinance our obligations as they come due.

Investors may experience dilution of their ownership interest due to the future issuance of additional shares of our Class A common stock.

We are in a capital intensive business, and may not have sufficient funds to finance the growth of our business, acquisitions or to support our projected capital expenditures. As a result, we have engaged in, and may require additional funds from further, equity or debt financings, including tax equity financing transactions or sales of preferred shares or convertible debt to complete future acquisitions, expansions and capital expenditures and pay the general and administrative costs of our business. In the future, we may issue our previously authorized and unissued securities, resulting in the dilution of the ownership interests of purchasers of our Class A common stock offered hereby. Under our amended and restated certificate of incorporation, we are authorized to issue 1,200,000,000 shares of Class A common stock and 100,000,000 shares of preferred stock with preferences and rights as determined by our Board. The potential issuance of additional shares of Class A common stock or preferred stock or convertible debt may create downward pressure on the trading price of our Class A common stock. We may also issue additional shares of our Class A common stock or other securities that are convertible into or exercisable for our Class A common stock in future public offerings or private placements for capital raising purposes or for other business


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purposes, potentially at an offering price, conversion price or exercise price that is below the trading price of our Class A common stock.

If securities or industry analysts do not publish or cease publishing research or reports about us, our business or our market, or if they change their recommendations regarding our Class A common stock adversely, the stock price and trading volume of our Class A common stock could decline.

The trading market for our Class A common stock will be influenced by the research and reports that industry or securities analysts may publish about us, our business, our market or our competitors. If any of the analysts who may cover us change their recommendation regarding our Class A common stock adversely, or provide more favorable relative recommendations about our competitors, the price of our Class A common stock would likely decline. If any analyst who may cover us were to cease coverage of our company or fail to regularly publish reports on us, we could lose visibility in the financial markets, which in turn could cause the stock price or trading volume of our Class A common stock to decline.

As a result of the Merger and Sponsorship Transaction, we are a “controlled company,” controlled by Brookfield, whose interest in our business may be different from ours or other holders of our Class A common stock.

As a result of the Merger and Sponsorship Transaction, Brookfield owns an approximate 51% interest in the Company. At the effective time of the Merger, SunEdison transferred all of the IDRs currently held by SunEdison to Brookfield IDR Holder pursuant to an Incentive Distribution Rights Transfer Agreement, Terra LLC entered into an amended and restated limited liability company agreement (the “New Terra LLC Agreement”) and Brookfield, the Company and certain of their respective affiliates entered into the Brookfield MSA. Pursuant to the terms of the New Terra LLC Agreement, cash distributions from Terra LLC will be allocated between the holders of the Class A units in Terra LLC and the holders of the IDRs according to a fixed formula. In addition, pursuant to the terms of the Brookfield MSA, Brookfield is entitled to certain fixed and variable management fees for services performed for the Company. As a result of these economic rights, Brookfield may have interests in our business that are different from our interests or the interests of the other holders of our Class A common stock.

In addition, pursuant to the Merger Agreement, if there has been a final resolution of certain specified litigation involving the Company, following the effective time of the Merger, the Company has agreed to issue a number of additional Class A shares to Brookfield for no additional consideration based on the amounts paid or accrued by the Company or any of its affiliates, including Brookfield, with respect to such litigation, calculated in accordance with specified formulas. As a result of this arrangement, Brookfield may have interests in the specified litigation that is different from our interests or the interests of the other holders of our Class A common stock.

Brookfield currently owns interests in, manages and controls, and may in the future own or acquire interests in, manage and/or control, other yield focused publicly listed and private electric power businesses that own clean energy assets, primarily hydroelectric facilities and wind assets, and other public and private businesses that own and invest in other real property and infrastructure assets. Brookfield may have conflicts or potential conflicts, including resulting from the operation by Brookfield of its other businesses, including its other yield focused electric power businesses, including with respect to Brookfield’s attention to and management of our business which may be negatively affected by Brookfield’s ownership and/or management of other power businesses and other public and private businesses that it owns, controls or manages.

For so long as Brookfield or another entity controls greater than 50% of the total outstanding voting power of our Class A common stock, we will be considered a “controlled company” for the purposes of the NASDAQ Global Select Market listing requirements. As a “controlled company,” we are permitted to opt out of the NASDAQ Global Select Market listing requirements that require (i) a majority of the members of our Board to be independent, (ii) that we establish a compensation committee and a nominating and governance committee, each comprised entirely of independent directors and (iii) an annual performance evaluation of the nominating and governance and compensation committees. We expect to rely on such exceptions with respect to having a majority of independent directors, establishing a compensation committee or nominating committee and annual performance evaluations of such committees. Brookfield may sell part or all of its stake in the Company, or may have its interest in the Company diluted due to future equity issuances, in each case, which could result in a loss of the “controlled company” exemption under the NASDAQ Global Select Market rules. We would then be required to comply with those provisions of the NASDAQ Global Select Market on which we currently or in the future may rely upon exemptions.

As a result of the Merger and Sponsorship Transaction, Brookfield and its affiliates control the Company and have the ability to designate a majority of the members of the Company’s Board.

The governance agreements entered into between the Company and Brookfield in connection with the Merger and


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Sponsorship Transaction provide Brookfield the ability to designate a majority of our Board to our Corporate Governance and Nominations Committee for nomination for election by our stockholders. Due to such agreements, and Brookfield’s approximate 51% interest in the Company, the ability of other holders of our Class A common stock to exercise control over the corporate governance of the Company will be limited. In addition, due to its approximate 51% interest in the Company, Brookfield has a substantial influence on our affairs and its voting power constitutes a large percentage of any quorum of our stockholders voting on any matter requiring the approval of our stockholders. As discussed in the risk factor entitled “As a result of the Merger and Sponsorship Transaction, we are a “controlled company,” controlled by Brookfield and its affiliates, whose interest in our business may be different from ours or other holders of our Class A common stock ” above, Brookfield may hold certain interests that are different from ours or other holders of our Class A common stock and there is no assurance that Brookfield will exercise its control over the Company in a manner that is consistent with our interests or those of the other holders of our Class A common stock.

Brookfield’s sponsorship may create significant conflicts of interest that may be resolved in a manner that is not in our best interest or the best interest of our shareholders.

Our sponsorship arrangements with Brookfield involve relationships that may give rise to conflicts of interest between us and our shareholders, on the one hand, and Brookfield, on the other hand. We rely on Brookfield to provide us with, among other things, strategic and investment management services. Although our sponsorship arrangements require Brookfield to provide us with a Chief Executive Officer, Chief Financial Officer and General Counsel who are dedicated to us on a full-time basis and have as their primary responsibility the provision of services to us, there is no requirement for Brookfield to act exclusively for us or for Brookfield to provide any specific individuals to us on an ongoing basis.

In certain instances, the interests of Brookfield may differ from our interests, including among other things with respect to the types of acquisitions we pursue, the timing and amount of distributions we make, the reinvestment of returns generated by our operations, the use of leverage when making acquisitions and the appointment of certain outside advisers and service providers. Although we believe the requirement for our Conflicts Committee to review and approve any potential conflict transactions between us and Brookfield should mitigate this risk, there can be no assurance that such review and approvals will result in a resolution that is entirely in our best interests or the best interests of our shareholders.

Brookfield exercises substantial influence over the Company and we are highly dependent on Brookfield.

We depend on the management and administration services provided by Brookfield pursuant to the Brookfield MSA. Other than our Chief Executive Officer, Chief Financial Officer and General Counsel, Brookfield personnel and support staff that provide services to us under the Brookfield MSA are not required to have as their primary responsibility the management and administration of us or to act exclusively for us and the Brookfield MSA does not require any specific individuals to be provided to us. Failing to effectively manage our current operations or to implement our strategy could have a material adverse effect on our business, financial condition and results of operations.

The departure of some or all of Brookfield’s professionals could prevent us from achieving our objectives.

We depend on the diligence, skill and business contacts of Brookfield’s professionals and the information and opportunities they generate during the normal course of their activities. Our future success will depend on the continued service of these individuals, who are not obligated to remain employed with Brookfield. Brookfield has experienced departures of key professionals in the past and may experience departures again in the future, and we cannot predict the impact that any such departures will have on our ability to achieve our objectives. The departure of a significant number of Brookfield’s professionals for any reason, or the failure to appoint qualified or effective successors in the event of such departures, could have a material adverse effect on our ability to achieve our objectives.

The role and ownership of Brookfield may change.

Our arrangements with Brookfield do not require Brookfield to maintain any ownership level in the Company. If Brookfield decides to sell part or all of its stake in the Company, or has its interest in the Company diluted due to future equity issuances, we could lose the benefit of the “controlled company” exemption for the purposes of the NASDAQ Global Select Market rules as discussed in the risk factor entitled “As a result of the Merger and Sponsorship Transaction, we are a “controlled company,” controlled by Brookfield, whose interest in our business may be different from ours or other holders of our Class A common stock.” Additionally, if Brookfield’s ownership interest falls below 25%, we would have the right to terminate the Brookfield MSA. Any decision by the Company to terminate the Brookfield MSA would trigger a termination of the Relationship Agreement. As a result, we cannot predict with any certainty the effect that any change in Brookfield’s ownership would have on the trading price of our shares or our ability to raise capital or make investments in the future.


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Risks Related to our Historic Relationship with SunEdison and the SunEdison Bankruptcy

We have transitioned away from our historical dependence on SunEdison for important corporate, project and other services, which involves management challenges and poses risks that may materially adversely affect our business, results of operations and financial condition.

Over the course of 2017, we engaged in efforts to transition away from our historical dependence on SunEdison for corporate, project and other services, including providing for critical systems and information technology infrastructure, by seeking to identify alternative service providers and to establish and manage new relationships, as well as develop our own capabilities and resources in these areas. These efforts include creating a separate stand-alone corporate organization, including, among other things, directly hiring employees and establishing our own accounting, information technology, human resources and other systems and infrastructure, and also include transitioning the project-level O&M and asset management services in-house or to third party service providers. These efforts are largely complete, however, although they were designed to mitigate risks posed by the SunEdison Bankruptcy, they involve a number of new risks and challenges that may materially adversely affect our business, results of operations and financial condition.

For example, we may be unable to replicate the corporate and project-level services we previously received, either through outsourcing or performing those services ourselves on terms or at similar historic costs or at all. The fees for services provided by Brookfield under the Brookfield MSA, which amount to $2.5 million per quarter for the first four quarters plus a certain variable component, and escalate thereafter, are higher than the fees that we were to pay under the SunEdison management services agreement, which were equal to 2.5% of the Company’s cash available for distribution to shareholders in 2016 and 2017 (not to exceed $7.0 million in 2016 or $9.0 million in 2017). In addition, in light of SunEdison’s familiarity with our assets, we may not be able to procure the same level of service either through our self-performance of these tasks or through outsourcing. We also continue to depend on a substantial number of outside contractors for accounting services and the costs for these services are substantially greater than those we would incur if we directly hired employees to perform the same services.

Finalizing these changes in connection with such transition may take longer than we expect, cost more than we expect, and divert management’s attention from other aspects of our business. We may also incur substantial legal and compliance costs in many of the jurisdictions where we operate. In addition, as we have limited experience in developing our own capabilities and resources, there is no assurance that we would ultimately be successful in our efforts in each of these areas, if at all, which could result in delays or disruptions in our business and operations.

Our historic relationship with SunEdison may adversely affect our relationships with current or potential counterparties.

We have important counterparties at every level of operations, including offtakers under the PPAs, corporate and project-level lenders and investors, suppliers and service providers. The SunEdison Bankruptcy may have damaged our relationships with our counterparties due to concerns about the SunEdison Bankruptcy and its impact on our business. These concerns may cause counterparties to be less willing to grant waivers or forbearances if needed for other matters and more likely to enforce contractual provisions or reduce utilization of our services (or the provision of supplies or services) where the counterparty has flexibility in volume or duration. These concerns may also cause our existing or potential new counterparties to be less likely to enter into new agreements or to demand more expensive or onerous terms, credit support, security or other conditions. Damage to our existing or potential future counterparty relationships may materially and adversely affect our business, financial condition and results of operations, including our growth strategy.

Risks Related to our Delayed Exchange Act Filings

Potential future delays in the filing of our reports with the SEC, as well as further delays in the preparation of audited financial statements at the project level, could have a material adverse effect.

The Company did not file with the SEC on a timely basis its Form 10-Ks for the years ended December 31, 2015 and 2016 and its Form 10-Qs for each of the quarters ended March 31, 2016, June 30, 2016, September 30, 2016, March 31, 2017 and June 30, 2017. The Company timely filed its Form 10-Q for the quarter ended September 30, 2017. During the period of these delays, we received notification letters from NASDAQ that granted extensions to regain compliance with NASDAQ’s continued listing requirements, subject to the requirement that we file our SEC reports and hold our annual meeting of stockholders by certain deadlines. While we are now current in our filing of periodic reports under the Securities and Exchange Act of 1934, as amended (the “Exchange Act”), and are in compliance with NASDAQ's continued listing requirements, in the event that any future periodic report is delayed, there is no assurance that we will be able to obtain further extensions from


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NASDAQ to maintain or regain compliance with NASDAQ’s continued listing requirements with respect to any such delayed periodic report. If we fail to obtain any such further extensions from NASDAQ, our Class A common stock would likely be delisted from the NASDAQ Global Select Market.

The delay in filing our Annual Reports on Form 10-K and our Quarterly Reports on Form 10-Q and related financial statements has impaired our ability to obtain financing and access the capital markets, and to the extent we fail to make timely filings in the future, our access to financing may be impaired. For example, as a result of the delayed filing of our periodic reports with the SEC, we will not be eligible to register the offer and sale of our securities using a short-form registration statement on Form S-3 until we have timely filed all periodic reports required under the Exchange Act for one year. Additional delays may also negatively impact our ability to obtain project financing and our ability to obtain waivers or forbearances to the extent of any defaults or breaches of project-level financing. An inability to obtaining financing may have a material adverse effect on our ability to grow our business, acquire assets through acquisitions or optimize our portfolio and capital structure. Additionally, a delay in audited financial statements may reduce the comfort of our Board with approving the payment of dividends.

Financial statements at the project-level have also been delayed over the course of 2016 and 2017. This delay created defaults under most of our non-recourse financing agreements, which have been substantially cured or waived as of the date hereof. To the extent any remaining defaults remain uncured or unwaived, or new defaults arise because of future delays in the completion of audited or unaudited financial statements, our subsidiaries may be restricted in their the ability to make distributions to us, or the related lenders may be entitled to demand repayment or enforce their security interests, which could have a material adverse effect on our business, results of operations, financial condition, our ability to pay dividends and our ability to comply with corporate-level debt covenants.

Item 1B. Unresolved Staff Comments.

None.

Item 2. Properties.

Our current portfolio consists of distributed generation solar facilities and utility-scale power plants that are located in the United States (including Puerto Rico), Canada, Chile and the United Kingdom with a combined nameplate capacity of 2,606.4 MW as of December 31, 2017. We have financed certain of our assets through project specific debt secured by the renewable energy facility's assets (mainly the renewable energy facility) or equity interests in such renewable energy facilities with no recourse to Terra LLC or Terra Operating LLC. See the table of our properties in Item 1. Business - Our Portfolio.
    
Distributed generation solar facilities
 
Distributed generation facilities provide customers with an alternative to traditional utility energy suppliers. Distributed resources are typically smaller in unit size and can be installed at a customer’s site, removing the need for lengthy transmission and distribution lines. By bypassing the traditional utility suppliers, distributed energy systems delink the customer’s price of power from external factors such as volatile commodity prices, costs of the incumbent energy supplier and some transmission and distribution charges. This makes it possible for distributed energy purchasers to buy energy at a predictable and stable price over a long period of time.

The PPAs for certain of our distributed generation solar facilities located in the United States allow the offtake purchaser to elect to purchase the facility from us at a price equal to the greater of a specified amount in the PPA or fair market value. In addition, certain of our PPAs allow the offtake purchaser to terminate the PPA if we do not meet certain prescribed operating thresholds or performance measures or otherwise by the payment of an early termination fee, which would require us to remove the renewable energy facility from the offtaker’s site. These operating thresholds and performance measures are readily achievable in the normal operation of the renewable energy facilities.

Utility-scale power plants

Our utility-scale solar generation facilities and wind facilities are our larger scale power plants where either the purchaser of the electricity is an electric utility, governmental entity or other third party or where power is delivered directly to the grid.



43


Item 3. Legal Proceedings.

See Note 19. Commitments and Contingencies to our consolidated financial statements included in this Annual Report on Form 10-K for disclosures concerning our legal proceedings, which disclosures are incorporated herein by reference.    
    
Item 4. Mine Safety Disclosures.

Not applicable.



44


PART II

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

Class A Common Stock

TerraForm Power's Class A common stock began trading on the NASDAQ Global Select Market under the symbol “TERP” on July 18, 2014. Prior to that, there was no public market for our Class A common stock.

Immediately prior to the effective time of the Merger, pursuant to the Settlement Agreement, SunEdison exchanged all of the Class B units held by SunEdison or any of its controlled affiliates in Terra LLC for 48,202,310 Class A shares of TerraForm Power, and as a result of this exchange, all shares of Class B common stock of TerraForm Power were automatically redeemed and retired. Our Class B common stock was not publicly traded. Pursuant to the Settlement Agreement, immediately following this exchange, we issued to SunEdison additional Class A shares of TerraForm Power such that immediately prior to the effective time of the Merger, SunEdison and certain of its affiliates held an aggregate number of Class A shares equal to 36.9% of the Company's fully diluted share count (which was subject to proration based on the Merger consideration election results as discussed in Note 15. Stockholders' Equity to our consolidated financial statements). After giving effect to these transactions and this proration, SunEdison and certain of its affiliates held an aggregate 34,273,879 Class A shares in TerraForm Power, which we registered in December of 2017, and these shares were distributed by SunEdison and certain of its affiliates under the plan of reorganization in connection with SunEdison's emergence from bankruptcy in December of 2017. At the effective time of the Merger, TerraForm Power also issued 65,144,459 Class A shares to Orion Holdings pursuant to the Merger Agreement, which are not registered.

Upon the consummation of the Merger, our certificate of incorporation was amended and restated. TerraForm Power's authorized shares of preferred stock and Class A common stock were increased to 100,000,000 shares and 1,200,000,000 shares, respectively. There are no other authorized classes of shares, and we do not have any issued shares of preferred stock.

As of February 28, 2018, there were 18 holders of record of TerraForm Power’s Class A common stock and the closing sale price per share of our Class A common stock on the NASDAQ Global Select Market was $11.51. Orion Holdings, a controlled affiliate of Brookfield, held 51% of TerraForm Power's Class A common stock as of such date.

The table below sets forth, for the periods indicated, the high and low sale prices per share of our Class A common stock on the NASDAQ Global Select Market for the periods indicated below:
 
 
High
 
Low
Quarter ended March 31, 2016
 
$
12.61

 
$
7.64

Quarter ended June 30, 2016
 
11.00

 
7.44

Quarter ended September 30, 2016
 
14.59

 
10.94

Quarter ended December 31, 2016
 
14.38

 
11.40

Quarter ended March 31, 2017
 
13.55

 
10.99

Quarter ended June 30, 2017
 
12.90

 
11.63

Quarter ended September 30, 2017
 
14.00

 
11.69

Quarter ended December 31, 2017
 
14.20

 
10.93


Dividends

On October 6, 2017, our Board declared the payment of a special cash dividend (the “Special Dividend”) to holders of record immediately prior to the effective time of the Merger in the amount of $1.94 per fully diluted share, which included the Company's issued and outstanding Class A shares, Class A shares issued to SunEdison pursuant to the Settlement Agreement (as described above) and Class A shares underlying outstanding restricted stock units of the Company under the Company's long-term incentive plan. The Special Dividend was paid on October 17, 2017. There were no other cash dividends declared or paid on our Class A common stock during the years ended December 31, 2017 and 2016.

On February 6, 2018, our Board declared a quarterly dividend with respect to our Class A common stock of $0.19 per share. The dividend is payable on March 30, 2018 to shareholders of record as of February 28, 2018. This dividend represents our first dividend payment under Brookfield sponsorship.


45



Stock Performance Graph

This performance graph below shall not be deemed “soliciting material” or to be “filed” with the SEC for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities under that section, and shall not be deemed to be incorporated by reference into any filing of the Company under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended.

The performance graph below compares TerraForm Power's cumulative total stockholder return on its Class A common stock from July 18, 2014 through December 31, 2017, with the cumulative total return of the Standard & Poor's 500 Composite Price Index, or the “S&P 500,” the NASDAQ Composite Index, as well as our peer group consisting of Atlantica Yield PLC; NextEra Energy Partners, LP; NRG Yield, Inc.; Pattern Energy Group Inc; and 8point3 Energy Partners LP.

The performance graph below compares each period assuming that $100 was invested on the initial public offering date in each of the Class A common stock of the Company, the stocks in the S&P 500, the NASDAQ Composite Index, our peer group, and that all dividends were reinvested.

Comparison of Cumulative Total Return
https://cdn.kscope.io/f4c1aef99ef6528fa659800937cdf5ef-totalreturnchart2017.jpg

Securities Authorized for Issuance under Equity Compensation Plans

For information regarding our equity compensation plans, see Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.


46


Item 6. Selected Financial Data.

Our historical selected financial data is presented in the following table. For all periods prior to our initial public offering (“IPO”) on July 23, 2014, the amounts shown in the table below represent the combination of TerraForm Power and Terra LLC, the accounting predecessor, and were prepared using SunEdison's historical basis in assets and liabilities. For all periods subsequent to the IPO, the amounts shown in the table below represent the results of TerraForm Power, which consolidates Terra LLC through its controlling interest. This historical data should be read in conjunction with the consolidated financial statements and the related notes thereto in Item 15. Exhibits, Financial Statements and Schedules and with Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.
 
 
Year Ended December 31,
(In thousands, except per share data)
 
2017
 
2016
 
2015
 
2014
 
2013
Statement of Operations Data:
 
 
 
 
 
 
 
 
 
 
Operating revenues, net
 
$
610,471

 
$
654,556

 
$
469,506

 
$
127,156

 
$
18,716

Operating costs and expenses:
 
 
 
 
 
 
 
 
 
 
Cost of operations
 
150,733

 
113,302

 
70,468

 
10,630

 
1,112

Cost of operations - affiliate
 
17,601

 
26,683

 
19,915

 
8,063

 
1,068

General and administrative expenses
 
139,874

 
89,995

 
55,811

 
20,984

 
289

General and administrative expenses - affiliate
 
13,391

 
14,666

 
55,330

 
19,144

 
5,158

Acquisition and related costs
 

 
2,743

 
49,932

 
10,177

 

Acquisition and related costs - affiliate
 

 

 
5,846

 
5,049

 

Loss on prepaid warranty - affiliate
 

 

 
45,380

 

 

Goodwill impairment
 

 
55,874

 

 

 

Impairment of renewable energy facilities
 
1,429

 
18,951

 

 

 

Depreciation, accretion and amortization expense
 
246,720

 
243,365

 
161,310

 
41,280

 
5,731

Formation and offering related fees and expenses
 

 

 

 
3,570

 

Formation and offering related fees and expenses - affiliate
 

 

 

 
1,870

 

Total operating costs and expenses
 
569,748

 
565,579

 
463,992

 
120,767

 
13,358

Operating income
 
40,723

 
88,977

 
5,514

 
6,389

 
5,358

Other expenses (income):
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
262,003

 
310,336

 
167,805

 
86,191

 
8,129

Loss on extinguishment of debt, net
 
81,099

 
1,079

 
16,156

 
(7,635
)
 

Gain on sale of renewable energy facilities
 
(37,116
)
 

 

 

 

(Gain) loss on foreign currency exchange, net
 
(6,061
)
 
13,021

 
19,488

 
14,007

 
(771
)
Loss on investments and receivables - affiliate
 
1,759

 
3,336

 
16,079

 

 

Other (income) expenses, net
 
(5,017
)
 
2,218

 
7,362

 
438

 

Total other expenses, net
 
296,667

 
329,990

 
226,890

 
93,001

 
7,358

Loss before income tax (benefit) expense
 
(255,944
)
 
(241,013
)
 
(221,376
)
 
(86,612
)
 
(2,000
)
Income tax (benefit) expense
 
(23,080
)
 
494

 
(13,241
)
 
(4,689
)
 
(88
)
Net loss
 
$
(232,864
)
 
$
(241,507
)
 
$
(208,135
)
 
$
(81,923
)
 
$
(1,912
)
Net loss attributable to Class A common stockholders
 
$
(164,189
)
 
$
(129,847
)
 
$
(79,886
)
 
$
(25,617
)
 
N/A

Basic and diluted loss per Class A common share
 
(1.65
)
 
(1.47
)
 
(1.25
)
 
(0.87
)
 
N/A

Dividends declared per Class A common share
 
1.94

 

 
1.01

 
0.44

 
N/A

 
 
 
 
 
 
 
 
 
 
 



47


 
 
As of December 31,
(In thousands)
 
2017
 
2016
 
2015
 
2014
 
2013
Balance Sheet Data:
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
 
$
128,087

 
$
565,333

 
$
626,595

 
$
468,554

 
$
1,044

Restricted cash
 
96,700

 
117,504

 
159,904

 
81,000

 
69,722

Renewable energy facilities, net
 
4,801,925

 
4,993,251

 
5,834,234

 
2,648,212

 
433,019

Long-term debt and financing lease obligations
 
3,598,800

 
3,950,914

 
4,562,649

 
1,699,765

 
441,650

Capital lease obligations
 

 

 

 

 
29,171

Total assets
 
6,387,021

 
7,705,865

 
8,217,409

 
3,680,423

 
593,327

Total liabilities
 
3,958,313

 
4,807,499

 
5,101,429

 
2,140,164

 
577,875

Redeemable non-controlling interests
 
58,340

 
180,367

 
175,711

 
24,338

 

Total stockholders' equity
 
2,370,368

 
2,717,999

 
2,940,269

 
1,515,921

 
15,452


Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following discussion and analysis should be read in conjunction with our audited consolidated financial statements and notes thereto contained herein. The results shown herein are not necessarily indicative of the results to be expected in any future periods. Unless otherwise indicated or otherwise required by the context, references in this section to “we,” “our,” “us,” or the “Company” refer to TerraForm Power, Inc. and its consolidated subsidiaries.

Overview

Our primary business strategy is to acquire, own and operate solar and wind assets in North America and Western Europe. We are the owner and operator of a 2,600 MW diversified portfolio of high-quality solar and wind assets, located primarily in the United States and underpinned by long-term contracts. Significant diversity across technologies and locations coupled with contracts across a large, diverse group of creditworthy counterparties significantly reduces the impact of resource variability on cash available for distribution and limits our exposure to any individual counterparty.

On April 21, 2016, SunEdison, Inc., our previous sponsor, and certain of its domestic and international subsidiaries voluntarily filed for protection under Chapter 11 of the U.S. Bankruptcy Code. In response to SunEdison’s financial and operating difficulties, we initiated a process for the exploration and evaluation of potential strategic alternatives for the Company. As described in Item 1. Business, this process resulted in our entry into the Merger Agreement on March 6, 2017 with affiliates of Brookfield. At the same time, we also entered into the Settlement Agreement and the Voting and Support Agreement with SunEdison to, among other things, facilitate the closing of the Merger and the settlement of claims between the Company and SunEdison.

On October 16, 2017, the Merger was consummated with TerraForm Power continuing as the surviving corporation in the Merger, and the Company entered into a suite of support and sponsorship arrangements with Brookfield and certain of its affiliates, as described in greater detail under Sponsorship Arrangements within Item 1. Business. In connection with the successful completion of the Merger and Sponsorship Transaction, Brookfield replaced SunEdison as our sponsor and all outstanding claims between us and SunEdison that may have existed prior to the closing of the Merger and Sponsorship Transaction were finally settled, and all agreements between the Company and the SunEdison Debtors were deemed rejected, subject to certain limited exceptions, without further liability, claims or damages on the part of the Company.

Our goal is to pay dividends to our shareholders that are sustainable on a long-term basis while retaining within our operations sufficient liquidity for recurring growth capital expenditures and general purposes. We expect to generate this return with a regular dividend, which we intend to grow at 5 to 8% per annum, that is supported by a target payout ratio of 80 to 85% of cash available for distribution and our stable cash flows. We expect to achieve this growth and deliver returns by focusing on the following initiatives:

Margin Enhancements:
We believe there is significant opportunity to enhance our cash flow through productivity enhancements by rationalizing our headcount and implementing a more efficient organizational structure. In addition, we plan to automate a number of processes that are currently very labor intensive and expect to realize cost savings


48


through reductions in O&M expenses and the in-sourcing of asset management and certain back office functions.

Organic Growth:
We plan to develop a robust organic growth pipeline comprised of opportunities to invest in our existing fleet on an accretive basis as well as add-on acquisitions across our scope of operations. We have identified a number of opportunities which we believe may be compelling to invest in our fleet, including asset repowerings, site expansions and potentially adding energy storage to existing sites.

Value-oriented acquisitions:
We expect to evaluate a number of acquisition opportunities with a focus on sourcing off-market transactions at more attractive valuations than auction processes. Our recently announced tender offer for the outstanding shares of Saeta Yield (as described in Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield within Item 1. Business) is an example of these acquisition opportunities. We believe that multi-faceted transactions such as take-privates and recapitalizations may enable us to acquire high quality assets at attractive relative values.
We have a right of first offer to acquire certain renewable power assets in North America and Western Europe owned by Brookfield and its affiliates. The ROFO portfolio currently stands at 3,500 MW. Over time, as Brookfield entities look to sell these assets, we will have the opportunity to make offers for these assets and potentially purchase them if the prices meet our investment objectives and are the most favorable offered to Brookfield. We also continue to maintain a call right over 0.5 GW (net) of operating wind power plants that are owned by a warehouse vehicle that was owned and arranged by SunEdison. SunEdison sold its equity interest in this warehouse vehicle to an unaffiliated third party in 2017.
    
We believe we are well positioned to benefit from Brookfield's deep operational expertise in owning, operating and developing renewable assets, as well as its significant deal sourcing capabilities and access to capital. Brookfield is a leading global alternative asset manager and has a more than 100-year history of owning and operating assets with a focus on renewable power, property, infrastructure and private equity. Brookfield has approximately $40 billion in renewable power assets under management, representing approximately 16,400 MW of generation capacity in 14 countries. It also employs over 2,000 individuals with extensive operating, development and power marketing capabilities and has a demonstrated ability to deploy capital in a disciplined manner, having developed or acquired 12,000 MW of renewable generation capacity since 2012.
    
Factors that Significantly Affect our Results of Operations and Business

We expect the following factors will affect our results of operations:

Transition to sponsorship by Brookfield

Throughout 2017, we worked to complete our transition away from our historical reliance on SunEdison for operational, systems and staffing support, among other things, as part of a strategic initiative to mitigate the adverse effects of the SunEdison Bankruptcy. Over the course of the year we made significant progress in this area and are now no longer reliant on SunEdison.

In light of the closing of the Merger and Sponsorship Transaction, in 2017 we also began to transition to Brookfield sponsorship of the Company. Our results of operations and business will be affected by the relative success of this transition. In the near term, we are targeting cost improvements by streamlining processes and optimizing our structure, which we expect can be achieved by rationalizing our headcount, adopting a more efficient organizational structure and in-sourcing certain back office functions. In the medium term, we are targeting costs savings in O&M by replacing high cost legacy O&M contracts across our wind fleet through either in-sourcing or renegotiating contracts with third party providers, depending on which alternative provides the best combination of cost and risk transfer, and improvements in fleet availability. We also expect to refocus the Company on growth initiatives that are developed organically and with the benefit of Brookfield’s deal sourcing capabilities. Our results of operations, business and growth prospects will depend on our success in achieving these cost improvements and growth strategy.



49


Offtake contracts

Our revenue is primarily a function of the volume of electricity generated and sold by our renewable energy facilities as well as, to a lesser extent, where applicable, the sale of green energy certificates and other environmental attributes related to energy generation. Our current portfolio of renewable energy facilities is generally contracted under long-term PPAs with creditworthy counterparties. As of December 31, 2017, the weighted average remaining life of our PPAs was 14 years. Pricing of the electricity sold under these PPAs is generally fixed for the duration of the contract, although some of our PPAs have price escalators based on an index (such as the consumer price index) or other rates specified in the applicable PPA.

The Company also generates RECs as it produces electricity. RECs are accounted for as governmental incentives and are not considered output of the underlying renewable energy facilities. These RECs are currently sold pursuant to agreements with third parties and a certain debt holder, and REC revenue is recognized as the underlying electricity is generated if the sale has been contracted with the customer. Under the terms of certain debt agreements with a creditor, SRECs are transferred directly to the creditor to reduce principal and interest payments due under solar program loans.

Project operations and generation availability

Our revenue is a function of the volume of electricity generated and sold by our renewable energy facilities. Generation availability refers to the actual amount of time a power generation asset produces electricity divided by the amount of time such asset is expected to produce electricity, which reflects anticipated maintenance and interconnection interruptions. We track generation availability as a measure of the operational efficiency of our business. The volume of electricity generated and sold by our renewable energy facilities during a particular period is impacted by the number of facilities that have achieved commercial operations, as well as both scheduled and unexpected repair and maintenance required to keep our facilities operational. For some of our plants, particularly our wind plants located in Texas, we sell a portion of the power output of the plant on a merchant basis into the wholesale power markets. Any uncontracted energy sales are dependent on the current or day ahead prices in the power markets. Certain of the wholesale markets have experienced volatility and negative pricing.

The costs we incur to operate, maintain and manage our renewable energy facilities also affect our results of operations. Equipment performance represents the primary factor affecting our operating results because equipment downtime impacts the volume of the electricity that we are able to generate from our renewable energy facilities. The volume of electricity generated and sold by our facilities will also be negatively impacted if any facilities experience higher than normal downtime as a result of equipment failures, electrical grid disruption or curtailment, weather disruptions, or other events beyond our control.

Seasonality and resource variability

The amount of electricity produced and revenues generated by our solar generation facilities is dependent in part on the amount of sunlight, or irradiation, where the assets are located. Shorter daylight hours in winter months result in less irradiation and the generation produced by these facilities will vary depending on the season. Irradiation can also be variable at a particular location from period to period due to weather or other meteorological patterns, which can affect operating results. As the great majority of our solar power plants are located in the Northern hemisphere, we expect our current solar portfolio’s power generation to be at its lowest during the first and fourth quarters of each year. Therefore, we expect our first and fourth quarter solar revenue generation to be lower than other quarters.

Similarly, the electricity produced and revenues generated by our wind power plants depend heavily on wind conditions, which are variable and difficult to predict. Operating results for renewable energy facilities vary significantly from period to period depending on the wind conditions during the periods in question. As our wind power plants are located in geographies with different profiles, there is some flattening of the seasonal variability associated with each individual wind power plant’s generation, and we expect that as the fleet expands the effect of such wind resource variability may be favorably impacted, although we cannot guarantee that we will purchase wind power plants that will achieve such results in part or at all. Historically, our wind production is greater in the first and fourth quarters which can partially offset the lower solar revenue expected to be generated in those quarters.

We do not expect seasonality to have a material effect on our ability to pay a regular dividend. We intend to mitigate the effects of any seasonality that we experience by reserving a portion of our cash available for distribution and otherwise maintain sufficient liquidity, including cash on hand in order to, among other things, facilitate the payment of dividends to our stockholders.



50


Cash distribution restrictions

In certain cases, we obtain project-level or other limited or non-recourse financing for our renewable energy facilities which may limit our ability to distribute funds to the Company. These limitations typically require that the project-level cash is used to meet debt obligations and fund operating reserves of the project company. These financing arrangements also generally limit our ability to distribute funds to the Company if defaults have occurred or would occur with the giving of notice or the lapse of time, or both. Over the course of 2016 and 2017, the Company’s ability to distribute funds from its renewable energy facilities was limited for substantially all of its renewable energy facilities with non-recourse financing due to project-level defaults related to the SunEdison Bankruptcy and the failure to timely deliver audited financial statements. Substantially all of those defaults have now been cured or waived. However, if we fail to timely deliver financial statements in the future, or other defaults occur and continue on our non-recourse financing arrangements, we could again be limited in our ability to distribute funds to TerraForm Power in order to pay corporate-level expenses and debt service obligations, as well as to pay dividends to the holders of our Class A common stock, and in our ability to comply with corporate-level debt covenants.

Renewable energy facility acquisitions and investments

Our long-term growth strategy is dependent on our ability to acquire additional clean power generation assets. Over the course of 2016 and 2017, we have been limited in our ability to grow the Company as a result of the SunEdison Bankruptcy and other risks that we faced. In connection with our transition to Brookfield sponsorship, we have renewed our focus on sustainable growth and opportunistic value driven acquisitions and see a robust opportunity for a sustainable growth strategy over the long-term. This growth is expected to be comprised of organic growth investments in our existing fleet, add-on acquisitions across our scope of operations and value-oriented opportunistic acquisitions, including the recently announced acquisition of Saeta Yield that is expected to close in the second quarter of 2018, subject to certain closing conditions, as discussed in Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield within Item 1. Business.
    
Clean energy has been one of the fastest growing sources of electricity generation in North America and globally over the past decade. We expect the renewable energy generation segment in particular to continue to offer high growth opportunities driven by:

the continued reduction in the cost of solar, wind and other renewable energy technologies, which will lead to grid parity in an increasing number of markets;
distribution charges and the effects of an aging transmission infrastructure, which enable renewable energy generation sources located at a customer’s site, or distributed generation, to be more competitive with, or cheaper than, grid-supplied electricity;
the replacement of aging and conventional power generation facilities in the face of increasing industry challenges, such as regulatory barriers, increasing costs of and difficulties in obtaining and maintaining applicable permits, and the decommissioning of certain types of conventional power generation facilities, such as coal and nuclear facilities;
the ability to couple renewable energy generation with other forms of power generation, creating a hybrid energy solution capable of providing energy on a 24/7 basis while reducing the average cost of electricity obtained through the system;
the desire of energy consumers to lock in long-term pricing of a reliable energy source;
renewable energy generation’s ability to utilize freely available sources of fuel, thus avoiding the risks of price volatility and market disruptions associated with many conventional fuel sources;
environmental concerns over conventional power generation; and
government policies that encourage development of renewable power, such as state or provincial renewable portfolio standard programs, which motivate utilities to procure electricity from renewable resources. In addition to renewable energy, we expect natural gas to grow as a source of electricity generation due to its relatively lower cost and lower environmental impact compared to other fossil fuel sources, such as coal and oil.

Our future growth will be dependent in part on our ability to acquire renewable energy assets from third parties, including our ability to make offers for assets in the ROFO Pipeline of Brookfield and its affiliates to the extent the applicable affiliate of Brookfield elects to sell such assets and we are able to make a successful offer under the terms of the Relationship Agreement.

Access to capital markets

Our ability to acquire additional clean power generation assets and manage our other commitments may be dependent on our ability to raise or borrow additional funds and access debt and equity capital markets, including the equity capital markets for our Class A shares, the corporate debt markets and the project finance market for project-level debt. We accessed


51


the capital markets several times in 2017, including in connection with our New Revolver, New Term Loan, the New Senior Notes due 2023 and the Senior Notes due 2028 (as defined and discussed in Financing Activities within Liquidity and Capital Resources below), each of which we incurred in the fourth quarter of 2017. We also plan to access the capital markets in connection with financing our recently announced acquisition of Saeta Yield that is expected to close in the second quarter of 2018. Limitations on our ability to access the corporate and project finance debt and equity capital markets in the future on terms that are accretive to our existing cash flows would be expected to negatively affect our results of operations, business and future growth.

Foreign exchange

Our operating results are reported in United States dollars. Currently, a substantial majority of our revenues and expenses are generated in U.S. Dollars. Historically, we have also had significant revenue and expenses generated in other currencies, including the British Pound and the Canadian dollar. This mix of currencies changed over the course of 2017 as a result of the closing of the sale of substantially all of our portfolio of solar power plants located in the U.K. (24 operating projects representing an aggregate 365.0 MW, the “U.K. Portfolio”) on May 11, 2017. This mix may continue to change in the future if we elect to alter the mix of our portfolio within our existing markets or elect to expand into new markets, including as a result of the recently announced acquisition of Saeta Yield, a Spanish corporation, that is expected to close in the second quarter of 2018. In addition, our investments (including intercompany loans) in renewable energy facilities in foreign countries are exposed to foreign currency fluctuations. As a result, we expect our revenues and expenses will be exposed to foreign exchange fluctuations in local currencies where our renewable energy facilities are located. To the extent we do not hedge these exposures, fluctuations in foreign exchange rates could negatively impact our profitability and financial position.

Key Metrics

Operating Metrics

Net nameplate capacity

We measure the electricity-generating production capacity of our renewable energy facilities in net nameplate capacity. Rated capacity is the expected maximum output a power generation system can produce without exceeding its design limits. Net nameplate capacity is the rated capacity of all of the renewable energy facilities we own adjusted to reflect our economic ownership of joint ventures and similar power generation facilities. We measure net nameplate capacity for solar generation facilities in MW (DC) and for wind power plants in MW (AC). The size of our renewable energy facilities varies significantly among the assets comprising our portfolio. We believe the combined net nameplate capacity of our portfolio is indicative of our overall production capacity and period to period comparisons of our net nameplate capacity are indicative of the growth rate of our business. Our renewable energy facilities had an aggregate net nameplate capacity of 2,606.4 MW as of December 31, 2017.

Gigawatt hours sold

Gigawatt hours sold refers to the actual volume of electricity sold by our renewable energy facilities during a particular period. We track gigawatt hours sold as an indicator of our ability to realize cash flows from the generation of electricity at our renewable energy facilities. Our GWh sold for solar generation facilities for the years ended December 31, 2017, 2016 and 2015 were 1,895 GWh, 2,225 GWh and 1,973 GWh, respectively. Our GWh sold for wind power plants for the years ended December 31, 2017, 2016 and 2015 were 5,381 GWh, 5,499 GWh and 1,489 GWh, respectively.



52


Consolidated Results of Operations

The amounts shown in the table below represent the results of TerraForm Power, which consolidates Terra LLC through its controlling interest. For the year ended December 31, 2017, the results of the Company include the operating results of Terra LLC, as well as $11.3 million of stock-based compensation expense and $0.9 million of interest expense for the Sponsor Line Agreement (as discussed and defined in Liquidity and Capital Resources below) that was entered into in the fourth quarter of 2017, which are reflected in the operating results of TerraForm Power. For the years ended December 31, 2016 and 2015, the results of the Company include the operating results of Terra LLC and $3.4 million and $12.1 million of stock-based compensation expense, respectively, which is reflected in the operating results of TerraForm Power. The following table illustrates the consolidated results of operations for the years ended December 31, 2017, 2016 and 2015:
 
 
Year Ended December 31,
(In thousands)
 
2017
 
2016
 
2015
Operating revenues, net
 
$
610,471

 
$
654,556

 
$
469,506

Operating costs and expenses:
 
 
 
 
 
 
Cost of operations
 
150,733

 
113,302

 
70,468

Cost of operations - affiliate
 
17,601

 
26,683

 
19,915

General and administrative expenses
 
139,874

 
89,995

 
55,811

General and administrative expenses - affiliate
 
13,391

 
14,666

 
55,330

Acquisition and related costs
 

 
2,743

 
49,932

Acquisition and related costs - affiliate
 

 

 
5,846

Loss on prepaid warranty - affiliate
 

 

 
45,380

Goodwill impairment
 

 
55,874

 

Impairment of renewable energy facilities
 
1,429

 
18,951

 

Depreciation, accretion and amortization expense
 
246,720

 
243,365

 
161,310

Total operating costs and expenses
 
569,748

 
565,579

 
463,992

Operating income
 
40,723

 
88,977

 
5,514

Other expenses (income):
 
 
 
 
 
 
Interest expense, net
 
262,003

 
310,336

 
167,805

Loss on extinguishment of debt, net
 
81,099

 
1,079

 
16,156

Gain on sale of renewable energy facilities
 
(37,116
)
 

 

(Gain) loss on foreign currency exchange, net
 
(6,061
)
 
13,021

 
19,488

Loss on investments and receivables - affiliate
 
1,759

 
3,336

 
16,079

Other (income) expenses, net
 
(5,017
)
 
2,218

 
7,362

Total other expenses, net
 
296,667

 
329,990

 
226,890

Loss before income tax (benefit) expense
 
(255,944
)
 
(241,013
)
 
(221,376
)
Income tax (benefit) expense
 
(23,080
)
 
494

 
(13,241
)
Net loss
 
(232,864
)
 
(241,507
)
 
(208,135
)
Less: Pre-acquisition net income of renewable energy facilities acquired from SunEdison
 

 

 
1,610

Net loss excluding pre-acquisition net income of renewable energy facilities acquired from SunEdison
 
(232,864
)
 
(241,507
)
 
(209,745
)
Less: Net income attributable to redeemable non-controlling interests
 
10,884

 
18,365

 
8,512

Less: Net loss attributable to non-controlling interests
 
(79,559
)
 
(130,025
)
 
(138,371
)
Net loss attributable to Class A common stockholders
 
$
(164,189
)
 
$
(129,847
)
 
$
(79,886
)








53


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

Operating Revenues, net

Operating revenues, net for the years ended December 31, 2017 and 2016 were as follows:
 
 
Year Ended December 31,
 
 
(In thousands, other than MW data)
 
2017
 
2016
 
Change
Energy:
 
 
 
 
 
 
Solar
 
$
232,791

 
$
258,114

 
$
(25,323
)
Wind
 
246,838

 
248,617

 
(1,779
)
Incentives including affiliates:
 
 
 
 
 
 
Solar
 
104,442

 
119,374

 
(14,932
)
Wind
 
26,400

 
28,451

 
(2,051
)
Total operating revenues, net
 
$
610,471

 
$
654,556

 
$
(44,085
)
 
 
 
 
 
 
 
GWh sold:
 
 
 
 
 
 
Solar
 
1,895

 
2,225

 
(330
)
Wind
 
5,381

 
5,499

 
(118
)
Total GWh sold
 
7,276

 
7,724

 
(448
)
 
 
 
 
 
 
 
Net nameplate capacity (MW):
 
 
 
 
 
 
Solar
 
1,075

 
1,452

 
(377
)
Wind
 
1,531

 
1,531

 

Total net nameplate capacity
 
2,606

 
2,983

 
(377
)
        
Energy revenue for our Solar segment decreased by $25.3 million during the year ended December 31, 2017, compared to the same period in 2016, primarily due to a $16.1 million decrease resulting from the sale of renewable energy facilities in the second quarter of 2017, a $5.7 million decrease due to lower Distributed Generation solar resource and a $7.7 million decrease due to lower Utility solar resource. Energy revenue for our Wind segment decreased by $1.8 million driven by a $13.6 million decrease resulting from lower Utility wind resource that was partially offset by a $6.7 million increase due to higher availability of our fleet and a $4.9 million increase in unrealized gains on commodity contract derivatives.

Incentive revenue for our Solar segment decreased by $14.9 million during the year ended December 31, 2017, compared to the same period in 2016, primarily due to a $19.6 million decrease resulting from the sale of renewable energy facilities in the second quarter of 2017 that was partially offset by a $9.1 million increase resulting from higher contracting of incentives as compared to the prior year. Incentive revenue for our Wind segment decreased by $2.1 million, primarily due to lower contracting of incentives as compared to the prior year.

Costs of Operations

Costs of operations for the years ended December 31, 2017 and 2016 were as follows:
 
 
Year Ended December 31,
 
 
(In thousands)
 
2017
 
2016
 
Change
Cost of operations:
 
 
 
 
 
 
Solar
 
$
54,766

 
$
27,934

 
$
26,832

Wind
 
95,967

 
85,368

 
10,599

Cost of operations - affiliate:
 
 
 
 
 
 
Solar
 
10,542

 
22,851

 
(12,309
)
Wind
 
7,059

 
3,832

 
3,227

Total cost of operations
 
$
168,334

 
$
139,985

 
$
28,349



54



Cost of operations for our Solar and Wind segments increased by $26.8 million and $10.6 million, respectively, during the year ended December 31, 2017, compared to the same period in 2016, primarily resulting from transitioning away from SunEdison for O&M and asset management services. Costs for asset management and O&M services provided by SunEdison are reported as cost of operations - affiliate, which decreased by $12.3 million for our Solar segment and increased by $3.2 million for our Wind segment, compared to the same period in the prior year. The increase in affiliate costs for our Wind segment was driven by higher inventory and repairs and maintenance costs. Total cost of operations, including cost of operations - affiliate, increased $28.3 million, and was driven by a $5.8 million loss on disposals of property and equipment resulting from the replacement of major components at certain of our wind power plants, higher costs for asset management and O&M services provided by unaffiliated third parties and higher costs for project-level accounting services. During 2016, SunEdison provided project-level accounting services to us pursuant to asset management agreements and the costs were recognized as cost of operations - affiliate. Due to the transition away from SunEdison, project accounting was brought in-house during 2017, and we have incurred significantly higher costs for these services due to our reliance on an hourly-based contractor workforce combined with the extraordinary level of effort involved with filing our past due annual and quarterly reports and regaining compliance with NASDAQ listing requirements. We expect the costs for project accounting to normalize during the second half of 2018 as we transition to an employee workforce and remain current in our accounting close procedures and financial reporting requirements.

General and Administrative Expenses

General and administrative expenses for the years ended December 31, 2017 and 2016 were as follows:
 
 
Year Ended December 31,
 
 
(In thousands)
 
2017
 
2016
 
Change
General and administrative expenses:
 
 
 
 
 
 
Solar
 
$
2,973

 
$
15,353

 
$
(12,380
)
Wind
 
2,276

 
2,387

 
(111
)
Corporate
 
134,625

 
72,255

 
62,370

Total general and administrative expenses
 
$
139,874

 
$
89,995

 
$
49,879

General and administrative expenses - affiliate:
 
 
 
 
 
 
Corporate
 
$
13,391

 
$
14,666

 
$
(1,275
)
    
General and administrative expenses increased by $49.9 million during the year ended December 31, 2017, compared to the same period in 2016, driven by a $62.4 million increase in corporate general and administrative expenses. The increase in corporate general and administrative expenses is primarily due to the incurrence of $27.0 million of success based advisory fees paid upon the consummation of the Merger, a $24.8 million increase in employee compensation costs, and an increase in professional fees for legal, accounting and advisory services resulting from transition to standalone operations and the Merger. The increase in employee compensation was driven by a $9.3 million increase in annual incentive and retention bonuses to retain key employees, a $7.9 million increase in stock-based compensation expense due to the vesting of all previously unvested RSUs triggered by the change in control upon the consummation of the Merger, a $3.7 million increase for severance and transition bonus costs incurred as a result of the Company's restructuring plan subsequent to the Merger and a $3.2 million increase in salaries and benefits costs due to directly hiring and retaining former employees of SunEdison.

General and administrative expenses - affiliate decreased by $1.3 million during the year ended December 31, 2017, compared to the same period in 2016, due to a $7.5 million decrease in the management and administrative services provided by SunEdison subsequent to the SunEdison Bankruptcy, partially offset by a $3.4 million base management fee charge recorded in the fourth quarter pursuant to the Brookfield MSA and a $2.8 million increase in stock-based compensation expense that was allocated to the Company for unvested equity awards held by the Company's employees in the stock of SunEdison, Inc. This increase was largely driven by the recognition of all previously unrecognized compensation cost pertaining to these awards as a result of the bankruptcy court's approval of SunEdison's plan of reorganization in July of 2017, which provided that all unvested equity awards in the stock of SunEdison, Inc. would be canceled.

Goodwill Impairment

The Company performed its annual impairment test of the carrying value of its goodwill as of December 1, 2016 and concluded that the goodwill balance of $55.9 million was fully impaired. The impairment was driven by a combination of factors, including lack of near-term growth in the operating segment. The impairment test determined there was no implied


55


value of goodwill, which resulted in an impairment charge of $55.9 million, which was recognized in goodwill impairment within the consolidated statement of operations for the year ended December 31, 2016. As a result of this charge, the Company did not have any goodwill as of December 31, 2017 or 2016.

Impairment of Renewable Energy Facilities
    
During 2016, we began exploring a sale of substantially all of our portfolio of residential rooftop solar assets located in the United States through a strategic sales process, and these assets were determined to meet the criteria to be classified as held for sale during the fourth quarter of 2016. Our analysis indicated that the carrying value of the assets exceeded the fair value less costs to sell, and thus an impairment charge of $15.7 million was recognized within impairment of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2016. We also recorded a $3.3 million charge within impairment of renewable energy facilities for the year ended December 31, 2016 due to the decision to abandon certain residential construction in progress assets that were not completed by SunEdison as a result of the SunEdison Bankruptcy.

We sold our remaining 0.3 MW of residential assets (that were not classified as held for sale as of December 31, 2016) during the third quarter of 2017. These assets did not meet the criteria for held for sale classification in the second quarter of 2017 but we determined that certain impairment indicators were present and as a result recognized an impairment charge of $1.4 million within impairment of renewable energy facilities in its consolidated statement of operations for the year ended December 31, 2017.

Depreciation, Accretion and Amortization Expense

Depreciation, accretion and amortization expense increased by $3.4 million during the year ended December 31, 2017, compared to the same period in 2016. This increase was primarily the result of a change in the estimated useful lives of the major components of our wind power plants, which was effective October 1, 2016, and the impact of capital additions placed in service during 2016. These increases were partially offset by a reduction in depreciation, accretion and amortization expense related to the classification of our U.K. Portfolio as held for sale as of the end of the first quarter of 2016.

Interest Expense, Net
 
 
Year Ended December 31,
 
 
(In thousands)
 
2017
 
2016
 
Change
Corporate-level
 
$
114,166

 
$
127,469

 
$
(13,303
)
Non-recourse:
 
 
 
 
 
 
Solar
 
70,439

 
97,123

 
(26,684
)
Wind
 
77,398

 
85,744

 
(8,346
)
Total interest expense, net
 
$
262,003

 
$
310,336

 
$
(48,333
)

Interest expense, net decreased by $48.3 million during the year ended December 31, 2017, compared to the same period in 2016. Interest expense under corporate-level long-term debt agreements decreased $13.3 million primarily due to lower outstanding balances under the Revolver. Interest expense under our non-recourse long-term debt agreements decreased by $26.7 million and $8.3 million for our Solar and Wind segments, respectively. The decrease at our Solar segment is primarily due to the recognition of $21.8 million of additional expense in the prior year as a result of the discontinuation of hedge accounting for the U.K. Portfolio's interest rate swaps in the second quarter of 2016, as well as lower interest expense in 2017 as a result of the sale of the U.K. Portfolio in May of 2017. The decrease at our Wind segment is primarily due to a $9.8 million decrease resulting from a $100.0 million prepayment of a non-recourse portfolio term loan in June 2017 and the repayment of the remaining outstanding principal balance on November 8, 2017.

Loss on Extinguishment of Debt, net
    
We incurred a net loss on extinguishment of debt of $81.1 million for the year ended December 31, 2017, compared to a loss of $1.1 million during the same period in the prior year. As discussed in Note 11. Long-term Debt to our consolidated financial statements, we issued the New Senior Notes due 2023 and the Senior Notes due 2028 and used the proceeds to redeem in full our existing Senior Notes due 2023. As a result, we recognized a $72.3 million loss on extinguishment of debt during the year ended December 31, 2017, consisting of the $50.7 million make-whole premium and the write-off of $21.6 million of unamortized deferred financing costs and debt discounts for the Senior Notes due 2023 as of the redemption date. On


56


October 17, 2017, we terminated the Revolver and entered into the New Revolver. As a result of this exchange, we recognized a $4.5 million loss on extinguishment of debt due to the write-off of unamortized deferred financing costs for the Revolver as of the termination date. The remaining loss on extinguishment of debt for 2017 was due to other reductions in borrowing capacity for the Revolver during 2017 prior to its termination and prepayments and a final repayment of a non-recourse portfolio term loan prior to the date a change of control would have occurred.
    
The loss on extinguishment of debt of $1.1 million for the year ended December 31, 2016 was driven by a reduction in borrowing capacity for the Revolver and corresponding write-off of a portion of the unamortized deferred financing costs, due to entering into the consent agreement and ninth amendment to the terms of the Revolver and a waiver agreement with the requisite lenders pertaining to third quarter reporting deliverables and compliance.

Gain on Sale of Renewable Energy Facilities
    
On May 11, 2017, we announced that Terra Operating LLC completed its previously announced sale of the U.K. Portfolio to Vortex Solar UK Limited, a renewable energy platform managed by the private equity arm of EFG Hermes, an investment bank. We recognized a gain on the sale of $37.1 million within gain on sale of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2017.

(Gain) Loss on Foreign Currency Exchange, net

We incurred a net gain on foreign currency exchange of $6.1 million for the year ended December 31, 2017 as compared to a net loss on foreign currency exchange of $13.0 million for the year ended December 31, 2016. The net gain for the year ended December 31, 2017 was primarily due to a $7.1 million unrealized gain on the remeasurement of intercompany loans (which were primarily denominated in Canadian dollars as of the end of 2017), offset by $1.0 million of realized and unrealized net losses on foreign currency derivatives. The net loss for the year ended December 31, 2016 was primarily due to a $14.4 million unrealized loss on the remeasurement of intercompany loans (which were primarily denominated in British pounds in 2016), which was offset by $1.3 million of realized and unrealized net gains on foreign currency derivatives.

Loss on Investments and Receivables - Affiliate

We incurred a net loss on investments and receivables - affiliate of $1.8 million due to the write-off of receivables from SunEdison upon the consummation of the Merger and the effectiveness of the Settlement Agreement with SunEdison on October 16, 2017. During the year ended December 31, 2016, we recognized a $3.3 million loss related to recording a bad debt reserve for outstanding receivables from debtors in the SunEdison Bankruptcy. 

Other (Income) Expenses, net

We recognized $5.0 million of other income, net for the year ended December 31, 2017 compared to $2.2 million of other expenses, net for the year ended December 31, 2016. We entered into a settlement agreement with insurers of one of our wind power plants with respect to insurance proceeds related to a battery fire that occurred at the wind power plant in 2012. We received $5.3 million of proceeds from this settlement in the fourth quarter of 2017. Other expenses, net for 2016 was primarily due to a $4.2 million loss on investment offset by $2.0 million of other miscellaneous income.

Income Tax (Benefit) Expense

Income tax benefit from continuing operations was $23.1 million for the year ended December 31, 2017, compared to income tax expense of $0.5 million during the same period in 2016. For the year ended December 31, 2017, the overall effective tax rate of 9.0% was different than the statutory rate of 35% primarily due to loss allocated to the recording of a valuation allowance on certain tax benefits attributed to the Company, loss allocated to non-controlling interests, the revaluation of deferred federal and state tax balances and the effect of foreign and state taxes. As of December 31, 2017, most jurisdictions were in a net deferred tax asset position. A valuation allowance is recorded against the deferred tax assets primarily because of the history of losses in those jurisdictions. Additionally, as discussed in Government Incentives and Legislation within Item 1. Business, the Tax Act was enacted on December 22, 2017, which provides that all U.S. corporations will be taxed at a flat rate of 21% for taxable years beginning January 1, 2018. For certain deferred tax assets and deferred tax liabilities, we have recorded a provisional net adjustment that increased the deferred tax benefit by $5.0 million for the year ended December 31, 2017.



57


Net Loss Attributable to Non-Controlling Interests

Net loss attributable to non-controlling interests, including redeemable non-controlling interests, was $68.7 million for the year ended December 31, 2017. This was the result of a $27.5 million loss attributable to SunEdison's interest in Terra LLC's net loss during the period prior to the consummation of the Merger on October 16, 2017, and a $41.2 million loss attributable to project-level tax equity partnerships. Net loss attributable to non-controlling interests, including redeemable non-controlling interests, was $111.7 million for the year ended December 31, 2016. This was the result of a $65.7 million loss attributable to SunEdison's interest in Terra LLC's net income during the year ended December 31, 2016 and a $46.0 million loss attributable to project-level tax equity partnerships.

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

Operating Revenues, net

Operating revenues, net for the years ended December 31, 2016 and 2015 were as follows:
 
 
Year Ended December 31,
 
 
(In thousands, other than MW data)
 
2016
 
2015
 
Change
Energy:
 
 
 
 
 
 
Solar
 
$
258,114

 
$
227,843

 
$
30,271

Wind
 
248,617

 
105,361

 
143,256

Incentives including affiliates:
 
 
 
 
 
 
Solar
 
119,374

 
118,190

 
1,184

Wind
 
28,451

 
18,112

 
10,339

Total operating revenues, net
 
$
654,556

 
$
469,506

 
$
185,050

 
 
 
 
 
 
 
GWh sold:
 
 
 
 
 
 
Solar
 
2,225

 
1,973

 
252

Wind
 
5,499

 
1,489

 
4,010

Total GWh sold
 
7,724

 
3,462

 
4,262

 
 
 
 
 
 
 
Net nameplate capacity (MW):
 
 
 
 
 
 
Solar
 
1,452

 
1,399

 
53

Wind
 
1,532

 
1,532

 

Total net nameplate capacity¹
 
2,984

 
2,931

 
53

________
(1) Excludes 36 MW of projects which were under construction as of December 31, 2015.



58


Energy revenues increased by $173.5 million during the year ended December 31, 2016, compared to the same period in 2015, due to:
(In thousands)
 
Solar
 
Wind
 
Total
Acquisitions of renewable energy facilities from SunEdison in 2015 and Q1 2016
 
$
24,429

 
$
18,941

 
$
43,370

Acquisition of Northern Lights in June 2015
 
5,513

 

 
5,513

Various other third party acquisitions in 2015
 
3,338

 

 
3,338

Timing of revenue under the MA Operating Massachusetts Virtual Net Metering PPAs
 
2,478

 

 
2,478

Lower revenue in U.K. due to weakening of the GBP partially offset by growth
 
(1,929
)
 

 
(1,929
)
Acquisition of Invenergy Wind in December 2015
 

 
157,669

 
157,669

Acquisition of First Wind in January 2015
 

 
8,885

 
8,885

Amortization of revenue contracts
 
(3,036
)
 
(31,879
)
 
(34,915
)
Unrealized loss on derivatives
 

 
(10,360
)
 
(10,360
)
Other
 
(522
)
 

 
(522
)
 
 
$
30,271

 
$
143,256

 
$
173,527


Incentive revenue increased by $11.5 million during the year ended December 31, 2016, compared to the same period in 2015, due to:
(In thousands)
 
Solar
 
Wind
 
Total
Acquisitions of renewable energy facilities from SunEdison in 2015 and Q1 2016
 
$
6,311

 
$

 
$
6,311

Primarily timing of contracting SRECs as well as pricing, volume and other differences
 
(10,920
)
 
6,777

 
(4,143
)
Lower revenue in U.K. due to weakening of the GBP partially offset by growth
 
(2,088
)
 

 
(2,088
)
Acquisition of Invenergy Wind in December 2015
 

 
2,516

 
2,516

Acquisition of First Wind in January 2015
 
648

 
1,186

 
1,834

Various other third party acquisitions in 2015
 
3,003

 

 
3,003

ITC amortization
 
5,427

 

 
5,427

Other
 
(1,197
)
 
(140
)
 
(1,337
)
 
 
$
1,184

 
$
10,339

 
$
11,523


Costs of Operations

Costs of operations for the years ended December 31, 2016 and 2015 were as follows:
 
 
Year Ended December 31,
 
 
(In thousands)
 
2016
 
2015
 
Change
Cost of operations:
 
 
 
 
 
 
Solar
 
$
27,934

 
$
30,007

 
$
(2,073
)
Wind
 
85,368

 
40,461

 
44,907

Cost of operations - affiliate:
 
 
 
 
 
 
Solar
 
22,851

 
17,943

 
4,908

Wind
 
3,832

 
1,972

 
1,860

Total cost of operations
 
$
139,985

 
$
90,383

 
$
49,602




59


Cost of operations increased by $42.8 million during the year ended December 31, 2016, compared to the same period in 2015, due to:
(In thousands)
 
Solar
 
Wind
 
Total
Increase in cost of operations relating to acquisitions of renewable energy facilities from SunEdison and unaffiliated third parties
 
$
4,075

 
$
44,907

 
$
48,982

Existing renewable energy facility cost of operations
 
(6,148
)
 

 
(6,148
)
 
 
$
(2,073
)
 
$
44,907

 
$
42,834


Cost of operations - affiliate increased by $6.8 million during the year ended December 31, 2016, compared to the same period in 2015, due to:
(In thousands)
 
Solar
 
Wind
 
Total
Increase in cost of operations - affiliate relating to acquisitions of renewable energy facilities from SunEdison and unaffiliated third parties
 
$
3,491

 
$
1,860

 
$
5,351

Existing renewable energy facility cost of operations - affiliate
 
1,417

 

 
1,417

 
 
$
4,908

 
$
1,860

 
$
6,768


General and Administrative Expenses

General and administrative expenses for the years ended December 31, 2016 and 2015 were as follows:
 
 
Year Ended December 31,
 
 
(In thousands)
 
2016
 
2015
 
Change
General and administrative expenses:
 
 
 
 
 
 
Solar
 
$
15,353

 
$
17,564

 
$
(2,211
)
Wind
 
2,387

 
2,019

 
368

Corporate
 
72,255

 
36,228

 
36,027

Total general and administrative expenses
 
$
89,995

 
$
55,811

 
$
34,184

General and administrative expenses - affiliate:
 
 
 
 
 
 
Corporate
 
$
14,666

 
$
55,330

 
$
(40,664
)

General and administrative expenses increased by $34.2 million compared to the year ended December 31, 2015, and general and administrative expenses - affiliate decreased by $40.7 million compared to the year ended December 31, 2015 due to:
(In thousands)
 
General and administrative expenses
 
General and administrative expenses - affiliate
Higher corporate costs due to professional fees for legal and accounting services as a result of the SunEdison Bankruptcy
 
$
22,770

 
$

Banker and advisory marketing services for the Merger
 
8,402

 

Higher corporate costs for employee retention and annual incentive awards
 
3,012

 

Decrease in the management and administrative services provided by SunEdison subsequent to the Bankruptcy
 

 
(40,664
)
Total change
 
$
34,184

 
$
(40,664
)

Pursuant to the management services agreement, SunEdison agreed to provide or arrange for other service providers to provide management and administrative services including legal, accounting, tax, treasury, project finance, information technology, insurance, employee benefit costs, communications, human resources and procurement to the Company. Subsequent to the SunEdison Bankruptcy, SunEdison continued to provide some management and administrative services to the Company, including employee compensation and benefit costs, human resources, information technology and communications, but stopped providing (or reimbursing the Company for) other services pursuant to the management services agreement. Pursuant to the Settlement Agreement entered into with SunEdison, and upon the consummation of the Merger with


60


affiliates of Brookfield on October 16, 2017, the management services agreement with SunEdison was rejected without further liability, claims or damages on the part of the Company.

Acquisition and Related Costs

Acquisition and related costs, including amounts related to affiliates, were $2.7 million during the year ended December 31, 2016, compared to $55.8 million during the same period in 2015. The decrease compared to 2015 is primarily due to the acquisition of wind power plants from First Wind Holdings, LLC, which was completed in the first quarter of 2015, the acquisition of Invenergy Wind power plants, which was completed in the fourth quarter of 2015, and the failed acquisition of the Vivint Operating Assets. These fees primarily consist of investment banker advisory fees and professional fees for legal and accounting services related to our acquisitions.

Goodwill Impairment

The Company performed its annual impairment test of the carrying value of its goodwill as of December 1, 2016 and concluded that the goodwill balance of $55.9 million was fully impaired. The impairment was driven by a combination of factors, including lack of near-term growth in the operating segment. The impairment test determined there was no implied value of goodwill, which resulted in an impairment charge of $55.9 million, which was recognized in goodwill impairment within the consolidated statement of operations for the year ended December 31, 2016. There was no goodwill impairment recognized during the year ended December 31, 2015.

Impairment of Renewable Energy Facilities

During 2016, the Company began exploring a sale of substantially all of its portfolio of residential rooftop solar assets located in the United States through a strategic sales process, and these assets were determined to meet the criteria to be classified as held for sale during the fourth quarter of 2016. The Company's analysis indicated that the carrying value of the assets exceeded the fair value less costs to sell, and thus an impairment charge of $15.7 million was recognized within impairment of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2016. The Company also recorded a $3.3 million charge within impairment of renewable energy facilities for the year ended December 31, 2016 due to the decision to abandon certain residential construction in progress assets that were not completed by SunEdison as a result of the SunEdison Bankruptcy. There was no impairment of renewable energy facilities recognized during the year ended December 31, 2015.

Depreciation, Accretion and Amortization Expense

Depreciation, accretion and amortization expense increased by $82.1 million during the year ended December 31, 2016, compared to the same period in 2015, due to:
(In thousands)
 
Solar
 
Wind
 
Total
Increases in depreciation, accretion and amortization relating to acquisitions of renewable energy facilities from SunEdison and unaffiliated third parties
 
$
16,851

 
$
83,343

 
$
100,194

Decrease in depreciation, accretion and amortization related to the U.K. Portfolio assets held for sale classification as of the first quarter of 2016
 
(18,139
)
 

 
(18,139
)
 
 
$
(1,288
)
 
$
83,343

 
$
82,055


Interest Expense, Net

Interest expense, net for the years ended December 31, 2016 and 2015 were as follows:    
 
 
Year Ended December 31,
 
 
(In thousands)
 
2016
 
2015
 
Change
Corporate-level
 
$
127,469

 
$
89,463

 
$
38,006

Non-recourse:
 
 
 
 
 
 
Solar
 
97,123

 
71,351

 
25,772

Wind
 
85,744

 
6,991

 
78,753

Total interest expense, net
 
$
310,336

 
$
167,805

 
$
142,531




61


Interest expense, net increased by $142.5 million during the year ended December 31, 2016, compared to the same period in 2015, due to increased indebtedness resulting from the acquisition of wind power plants and increased corporate-level indebtedness under the Revolver and the issuance of the Senior Notes due 2025. In addition, during the second quarter, the Company discontinued hedge accounting for interest rate swaps that were previously designated as cash flow hedges of the forecasted interest payments pertaining to variable rate project debt in the U.K. Portfolio. This resulted in the reclassification of $16.9 million of losses from accumulated other comprehensive income into interest expense. Subsequent to the discontinuation of hedge accounting, the Company recognized additional unrealized losses of $7.3 million pertaining to these interest rate swaps that are also reported in interest expense. During the year ended December 31, 2015, we reported an inconsequential amount of interest income related to interest rate swap derivatives not designated as hedges within interest expense, net in the consolidated statement of operations.

Loss on Extinguishment of Debt, net
    
We incurred a net loss on extinguishment of debt of $1.1 million for the year ended December 31, 2016, driven by a reduction in borrowing capacity for the Revolver and corresponding write-off of a portion of the unamortized deferred financing costs, due to the Company entering into the consent agreement and ninth amendment to the terms of the Revolver and a waiver agreement with the requisite lenders pertaining to third quarter reporting deliverables and compliance. The net loss on extinguishment of debt of $16.2 million for the year ended December 31, 2015, was primarily due to the termination of a corporate-level term loan and related interest rate swap, the exchange of the previous revolver to the Revolver, prepayment of premium paid in conjunction with the payoff of First Wind indebtedness at the acquisition date and termination of financing lease obligations upon acquisition of the Duke Operating portfolio.

Loss on Foreign Currency Exchange, net

We incurred a net loss on foreign currency exchange of $13.0 million for the year ended December 31, 2016, primarily due to a $14.4 million unrealized loss on the remeasurement of intercompany loans, which are primarily denominated in British pounds. These remeasurement losses were offset by $1.3 million of realized and unrealized net gains on foreign currency derivatives.

Loss on Investments and Receivables - Affiliate

We incurred a net loss on investments and receivables - affiliate of $3.3 million and $16.1 million during the years ended December 31, 2016 and 2015, respectively. We recognized $3.3 million and $4.8 million loss during 2016 and 2015, respectively, related to recording a bad debt reserve for outstanding receivables from debtors in the SunEdison Bankruptcy. The year ended December 31, 2015, also includes an $11.3 million loss on investment due to residential project cancellations driven by the SunEdison Bankruptcy.

Other expenses, net

Other expenses were $2.2 million for the year ended December 31, 2016. This was primarily due to $4.2 million loss on the investments offset by $2.0 million of other miscellaneous income. Other expenses were $7.4 million for the year ended December 31, 2015. This was primarily due to $4.2 million loss on investments and $3.2 million of other miscellaneous loss.

Income Tax Expense (Benefit)

Income tax expense from continuing operations was $0.5 million for the year ended December 31, 2016, compared to an income tax benefit of $13.2 million during the same period in 2015. For the year ended December 31, 2016, the overall effective tax rate was different than the statutory rate of 35% primarily due to loss allocated to the recording of a valuation allowance on certain tax benefits attributed to the Company, loss allocated to non-controlling interests, the impairment of goodwill at Capital Dynamics, and the effect of state taxes. The benefit in 2015 was primarily driven by the intraperiod allocation rules under ASC 740, as the Company recognized $14.6 million of offsetting income tax expense in other comprehensive loss. As of December 31, 2016, most jurisdictions are in a net deferred tax asset position. A valuation allowance is recorded against the deferred tax assets primarily because of the history of losses in those jurisdictions.

Net Loss Attributable to Non-Controlling Interests

Net loss attributable to non-controlling interests including redeemable non-controlling interests, was $111.7 million for the year ended December 31, 2016. This was primarily the result of a $65.7 million loss attributable to SunEdison's interest in Terra LLC's net income during the year ended December 31, 2016 and a $46.0 million loss attributable to project-level tax


62


equity partnerships. Net loss attributable to non-controlling interests was $129.9 million for the year ended December 31, 2015. This was primarily the result of $51.5 million loss attributable to SunEdison's and R/C US Solar Investment Partnership, L.P's (“Riverstone”) interest in Terra LLC's net income during the year ended December 31, 2015 and a $72.4 million loss attributable to project-level tax equity partnerships.

Liquidity and Capital Resources

Capitalization

A key element to our financing strategy is to raise the majority of our debt in the form of project specific non-recourse borrowings at our subsidiaries with investment grade metrics. Going forward, we intend to primarily finance acquisitions or growth capital expenditures using long-term non-recourse debt that fully amortizes within the asset's contracted life at investment grade metrics, as well as retained cash flows from operations and issuance of equity securities through public markets. Furthermore, we intend to further reduce corporate leverage by adding leverage at the project level and repaying corporate debt with proceeds from the planned project financings.

The following table summarizes the total capitalization and debt to capitalization as of December 31, 2017 and 2016:
 
 
As of December 31,
(In thousands)
 
2017
 
2016
Revolving Credit Facility1
 
$
60,000

 
$
552,000

Senior Notes2
 
1,500,000

 
1,250,000

New Term Loan3
 
350,000

 

Non-recourse long-term debt, including current portion4
 
1,732,516

 
2,201,939

Long-term indebtedness, including current portion5
 
$
3,642,516

 
$
4,003,939

Total stockholders' equity and redeemable non-controlling interests
 
2,428,708

 
2,898,366

Total capitalization
 
$
6,071,224

 
$
6,902,305

Debt to total capitalization
 
60
%
 
58
%
———
(1)
Represents draws on our senior secured corporate revolving credit facility. See the Financing Activities section below for discussion regarding our termination of our existing revolving credit facility and concurrent entry into a new revolving credit facility in the fourth quarter of 2017.
(2)
Corporate senior notes. See the Financing Activities section below for discussion regarding 2017 activity.
(3)
Senior secured term loan facility entered into in the fourth quarter of 2017. See the Financing Activities section below for further discussion.
(4)
Asset-specific, non-recourse borrowings and financing lease obligations secured against the assets of certain project companies.
(5)
Represents total principal due for long-term debt and financing lease obligations, including the current portion, which excludes $43.7 million and $53.0 million of unamortized debt discounts and deferred financing costs as of December 31, 2017 and 2016, respectively.
 
Liquidity Position

We operate with sufficient liquidity to enable us to fund dividends, growth initiatives, capital expenditures and withstand sudden adverse changes in economic circumstances or short-term fluctuations in resource. Principal sources of funding are cash flows from operations, revolving credit facilities (including our Sponsor Line as discussed and defined below), debt capacity at our projects, non-core asset sales and proceeds from the issuance of equity securities through public markets.



63


The following table summarizes corporate liquidity and available capital as of December 31, 2017 and 2016:
 
 
As of December 31,
(In thousands)
 
2017
 
2016
Unrestricted corporate cash
 
$
46,810

 
$
478,357

Project-level distributable cash
 
21,180

 
29,383

Cash available to corporate
 
67,990

 
507,740

Credit facilities:
 
 
 
 
Authorized credit facility1
 
450,000

 
625,000

Draws on credit facility
 
(60,000
)
 
(552,000
)
Revolving commitments
 
(102,637
)
 
(68,867
)
Sponsor Line2
 
500,000

 

Available portion of credit facilities
 
787,363

 
4,133

Corporate liquidity
 
$
855,353

 
$
511,873

Other project-level unrestricted cash
 
60,097

 
57,593

Project-level restricted cash3
 
96,700

 
117,504

Project-level credit commitments
 
2,800

 
3,765

Available capital
 
$
1,014,950

 
$
690,735

———
(1)
See the Financing Activities section below for discussion regarding our termination of our existing revolving credit facility and concurrent entry into a new revolving credit facility in the fourth quarter of 2017. The total borrowing capacity under this new facility was increased to $600.0 million on February 6, 2018 as discussed below. On March 6, 2018, we entered into certain Letter of Credit Facilities, pursuant to which we are required to maintain minimum liquidity of $400.0 million under this new revolving credit facility.
(2)
As discussed in the Financing Activities section below, the Sponsor Line may only be used to fund all or a portion of certain funded acquisitions or growth capital expenditures.
(3)
Represents short-term and long-term restricted cash and includes $21.7 million of cash trapped at our project-level subsidiaries which is presented as current restricted cash as the cash balances were subject to distribution restrictions related to debt defaults that existed as of the balance sheet date (see Note 2. Summary of Significant Accounting Policies to our consolidated financial statements for additional details). The amount of trapped cash that remains as of the date of the issuance of this Annual Report on Form 10-K is $11.3 million and is not needed for us to meet our cash flow needs. We expect to obtain waivers for the remaining defaults in the near-term and do not expect these defaults to affect our ability to meet our liquidity requirements and meet corporate credit facility covenants.

Recently Announced Tender Offer

As discussed in Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield within Item 1. Business, on February 7, 2018, we announced a voluntary tender offer for 100% of the outstanding shares of Saeta Yield, and we expect this acquisition to close in the second quarter of 2018, subject to certain closing conditions. We intend to finance this acquisition with a $400 million equity issuance of our Class A common stock and the remaining $800 million will be financed from available liquidity, which is expected to include borrowings under the Sponsor Line and the New Revolver. We expect to repay these borrowings with a combination of sources, including new non-recourse financings of our currently unencumbered wind and solar assets and certain cash released from Saeta Yield's assets. We also entered into a support agreement with Brookfield on February 6, 2018 pursuant to which they have agreed to provide a Back-Stop to us for up to 100% of our expected equity offering if the offering price per Class A share of our common stock in the equity offering equals the five-day volume weighted average price of the Class A shares ending the trading day prior to our announcement of the Tender Offer, which was $10.66 per share, subject to certain conditions as discussed in Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield within Item 1. Business. On March 6, 2018, we entered into certain Letter of Credit Facilities, pursuant to which two banks posted a bank guarantee with the CNMV for the maximum amount payable in the Tender Offer. Under the terms of the Letter of Credit Facilities, we are required to maintain minimum liquidity requirements of $500.0 million under the Sponsor Line Agreement and $400.0 million under the New Revolver. These minimum liquidity requirements may limit our ability to pursue or fund acquisitions or growth capital expenditures other than an acquisition of Saeta Yield pursuant to the Tender Offer.


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Financing Activities

New Revolver    

On October 17, 2017, Terra Operating LLC entered into a new senior secured revolving credit facility (the “New Revolver”). The New Revolver consists of a revolving credit facility in an initial amount of $450.0 million, available for revolving loans and letters of credit, which Terra Operating LLC subsequently elected to increase to $600.0 million on February 6, 2018. The New Revolver matures on the four-year anniversary of the closing date of such facility and was used to refinance the Company’s existing revolving credit facility ($250.0 million of revolving loans were initially drawn and used to repay a portion of the outstanding borrowings under the existing revolving credit facility) and will be used for other general corporate purposes and working capital requirements of Terra Operating LLC. Subsequent to the initial issuance, an additional $15.0 million of revolving loans were drawn during the fourth quarter of 2017 and $205.0 million of revolving loans were repaid, primarily using $50.0 million of the proceeds from the issuance of the New Term Loan (as defined below) and $150.0 million of the proceeds from the issuance of the New Senior Notes due 2023 and Senior Notes due 2028 (both defined below). The New Revolver is secured equally and ratably with the New Term Loan.

Senior Notes Supplemental Indentures, New Issuances and Redemption

On August 11, 2017, Terra Operating LLC announced the successful completion of a consent solicitation from holders of its Senior Notes due 2023 and its Senior Notes due 2025 to obtain a waiver of the requirement to make an offer to repurchase the respective Senior Notes upon the occurrence of a change of control that would result from the consummation of the Merger. Terra Operating LLC received consents from the holders of a majority of the aggregate principal amount of each series of the Senior Notes outstanding as of the record date and paid a consent fee to each consenting holder of $1.25 per $1,000 principal amount of such series of the Senior Notes for which such holder delivered its consent. Upon the closing of the Merger, Terra Operating LLC also paid a success fee of $1.25 per $1,000 principal amount of each series of the Senior Notes for which such consenting holder delivered its consent.

On December 12, 2017, Terra Operating LLC issued $500.0 million of 4.25% senior notes due 2023 at an offering price of 100% of the principal amount (the “New Senior Notes due 2023”) and $700.0 million of 5.00% senior notes due 2028 at an offering price of 100% of the principal amount (the “Senior Notes due 2028”). Terra Operating LLC used the proceeds to redeem in full its existing Senior Notes due 2023, of which $950.0 million remained outstanding, at a redemption price that included a make-whole premium of $50.7 million, plus accrued and unpaid interest, and to repay $150.0 million of revolving loans outstanding under the New Revolver.

Sponsor Line Agreement

On October 16, 2017, TerraForm Power entered into a credit agreement (the “Sponsor Line Agreement”) with Brookfield and one of its affiliates. The Sponsor Line Agreement establishes a $500.0 million secured revolving credit facility and provides for the lenders to commit to make LIBOR loans to us during a period not to exceed three years from the effective date of the Sponsor Line Agreement (subject to acceleration for certain specified events). The Sponsor Line Agreement may only be used to fund all or a portion of certain funded acquisitions or growth capital expenditures. The Sponsor Line Agreement will terminate, and all obligations thereunder will become payable, no later than October 16, 2022. As of December 31, 2017, there were no amounts drawn under the Sponsor Line Agreement.

New Term Loan

On November 8, 2017, Terra Operating LLC entered into a 5-year $350 million senior secured term loan (the “New Term Loan”), which was used to repay $300.0 million of outstanding borrowings under a non-recourse portfolio term loan prior to the date a change of control default would have occurred and $50.0 million of revolving loans outstanding under the New Revolver. The New Term Loan is secured and guaranteed equally and ratably with the New Revolver.

See Note 11. Long-term Debt to our consolidated financial statements for further discussion of these financing activities.

Debt Service Obligations

We remain focused on refinancing near-term facilities on acceptable terms and maintaining a manageable maturity ladder. We do not anticipate material issues in addressing our borrowings through 2022 on acceptable terms and will do so


65


opportunistically based on the prevailing interest rate environment.

The aggregate contractual payments of long-term debt due after December 31, 2017, including financing lease obligations and excluding amortization of debt discounts, premiums and deferred financing costs, as stated in the financing agreements, are as follows:
(In thousands)
 
20181
 
2019
 
2020
 
2021
 
2022
 
Thereafter
 
Total
Maturities of long-term debt and financing lease obligations2
 
$
162,597

 
$
110,512

 
$
105,305

 
$
108,408

 
$
596,732

 
$
2,558,962

 
$
3,642,516

—————
(1)
Includes $60.0 million of New Revolver indebtedness, of which we repaid $42.0 million with cash on hand in the first quarter of 2018.
(2)
Represents the contractual principal payment due dates for our long-term debt and does not reflect the reclassification of $239.7 million of long-term debt to current as a result of debt defaults under certain of our non-recourse financing arrangements (see Note 11. Long-term Debt to our consolidated financial statements for further discussion).

Cash Dividends to Investors

On October 6, 2017, our Board declared the payment of the Special Dividend to holders of record immediately prior to the effective time of the Merger in the amount of $1.94 per fully diluted share, which included the Company's issued and outstanding Class A shares, Class A shares issued to SunEdison pursuant to the Settlement Agreement and Class A shares underlying outstanding restricted stock units of the Company under the Company’s long-term incentive plan. The Special Dividend was paid on October 17, 2017.

On February 6, 2018, our Board declared a quarterly dividend with respect to our Class A common stock of $0.19 per share. The dividend is payable on March 30, 2018 to shareholders of record as of February 28, 2018. This dividend represents our first dividend payment under Brookfield sponsorship.

Incentive Distribution Rights
    
IDRs represented the right to receive increasing percentages (15.0%, 25.0% and 50.0%) of Terra LLC’s quarterly distributions after the Class A Units, Class B units, and Class B1 units of Terra LLC (as applicable) received quarterly distributions in an amount equal to $0.2257 per unit and the target distribution levels were achieved. SunEdison held 100% of the IDRs from the completion of the IPO up until the consummation of the Merger. There were no IDR payments made by us during the years ended December 31, 2017, 2016 and 2015.

In connection with the Settlement Agreement, SunEdison transferred all of the outstanding IDRs of Terra LLC held by SunEdison or certain of its affiliates to Brookfield IDR Holder at the effective time of the Merger, and the Company and Brookfield IDR Holder entered into the New Terra LLC Agreement. The New Terra LLC Agreement, among other things, reset the IDR thresholds of Terra LLC to establish a first distribution threshold of $0.93 per share of Class A common stock and a second distribution threshold of $1.05 per share of Class A common stock. As a result of this amendment and restatement, amounts distributed from Terra LLC will be distributed on a quarterly basis as follows:

first, to the Company in an amount equal to the Company’s outlays and expenses for such quarter;
second, to holders of Class A units, until an amount has been distributed to such holders of Class A units that would result, after taking account of all taxes payable by the Company in respect of the taxable income attributable to such distribution, in a distribution to holders of shares of Class A common stock of $0.93 per share (subject to adjustment for distributions, combinations or subdivisions of shares of Class A common stock) if such amount were distributed to all holders of shares of Class A common stock;
third, 15% to the holders of the IDRs and 85% to the holders of Class A units until a further amount has been distributed to holders of Class A units in such quarter that would result, after taking account of all taxes payable by the Company in respect of the taxable income attributable to such distribution, in a distribution to holders of shares of Class A common stock of an additional $0.12 per share (subject to adjustment for distributions, combinations or subdivisions of shares of Class A common stock) if such amount were distributed to all holders of shares of Class A common stock; and
thereafter, 75% to holders of Class A units and 25% to holders of the IDRs.



66


Cash Flow Discussion
    
We use traditional measures of cash flow, including net cash flows from operating activities, investing activities and financing activities to evaluate our periodic cash flow results.

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

The following table reflects the changes in cash flows for the comparative periods:
(In thousands)
 
Year Ended December 31,
 
 
 
2017
 
2016
 
Change
Net cash provided by operating activities
 
$
67,197

 
$
191,809

 
$
(124,612
)
Net cash provided by (used in) investing activities
 
206,272

 
(49,933
)
 
256,205

Net cash used in financing activities
 
(789,513
)
 
(187,194
)
 
(602,319
)

Net Cash Provided By Operating Activities
    
Net cash provided by operating activities for the year ended December 31, 2017 was $67.2 million as compared to $191.8 million for the same period in the prior year. The decrease in operating cash flow of $124.6 million was primarily driven by a $51.4 million decrease in operating revenues (excluding unrealized losses on commodity contract derivatives, recognition of deferred revenue and amortization of favorable and unfavorable rate revenue contracts, net) and a $61.1 million increase in operating costs (excluding non-cash items). The decrease in operating revenues was primarily due to a $35.7 million decrease resulting from the sale of renewable energy facilities in the first half of 2017, $13.4 million of lower solar resource and $13.6 million of lower wind resource, partially offset by a $6.7 million increase due to higher availability of our wind fleet. In addition, the timing of sales and collections resulted in a $6.1 million decrease in cash receipts related to accounts receivable. The increase in operating costs (excluding non-cash items) was primarily driven by $27.0 million of success-based advisory fees paid upon the consummation of the Merger, higher employee compensation and retention costs and higher professional fees for legal, accounting and advisory services resulting from the transition to standalone operations and the Merger. The timing of payments related to accounts payable, accrued expenses and other current liabilities resulted in a $41.6 million decrease in operating cash flow primarily due to a $9.75 million payment for the full settlement of claims under the Eastern Maine Electric Cooperative litigation (see Note 19. Commitments and Contingencies to our consolidated financial statements for further details) and a $30.7 million decrease in accrued interest driven by the payment of interest accrued under our Senior Notes due 2023 as of December 31, 2016 on February 1, 2017, with no corresponding accrual as of December 31, 2017 as these Senior Notes were redeemed in full on December 12, 2017. The impact of the decrease in accrued interest for the Senior Notes due 2023 was largely offset by lower interest expense and corresponding cash payments on non-recourse indebtedness as a result of the sale of the U.K. Portfolio in the second quarter, which resulted in a $17.7 million decrease, and a $7.3 million decrease resulting from prepayments and the final repayment in 2017 of the outstanding principal amount under a non-recourse portfolio term loan the Company had.

Net Cash Provided By (Used In) Investing Activities

Net cash provided by investing activities for the year ended December 31, 2017 was $206.3 million, which was primarily due to $183.2 million of net proceeds received from the sale of renewable energy facilities and $15.5 million of proceeds received from a government rebate for certain costs incurred for capital expenditures. Net cash used in investing activities for the year ended December 31, 2016 was $49.9 million, which included $45.9 million of cash paid to third parties for the construction of renewable energy facilities and other capital expenditures and $4.1 million of cash paid for third party acquisitions, net of cash and restricted cash acquired.

Net Cash Used In Financing Activities

Net cash used in financing activities for the year ended December 31, 2017 was $789.5 million, which was primarily driven by the $950.0 million repayment of the Senior Notes due 2023 principal along with the $50.7 million make-whole redemption premium, $492.0 million of net repayments on our corporate-level revolving credit facility borrowings, $569.5 million of principal payments and prepayments on non-recourse long-term debt and the Special Dividend payment of $285.5 million, which was partially offset by $495.0 million of net proceeds from the issuance of the New Senior Notes due 2023, $693.0 million of net proceeds from the issuance of the Senior Notes due 2028 and $344.7 million of net proceeds from the issuance of the New Term Loan. Net cash used in financing activities for the year ended December 31, 2016 was $187.2 million, which was primarily driven by $156.0 million of principal payments on non-recourse long-term debt and $103.0


67


million of repayments on revolving credit facility borrowings, partially offset by $86.7 million of net proceeds from non-recourse financing arrangements.

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

The following table reflects the changes in cash flows for the comparative periods:
(In thousands)
 
Year Ended December 31,
 
 
 
2016
 
2015
 
Change
Net cash provided by operating activities
 
$
191,809

 
$
124,260

 
$
67,549

Net cash used in investing activities
 
(49,933
)
 
(3,114,340
)
 
3,064,407

Net cash (used in) provided by financing activities
 
(187,194
)
 
3,238,505

 
(3,425,699
)

Net Cash Provided By Operating Activities

Net cash provided by operating activities for the year ended December 31, 2016 was $191.8 million, which represents an increase of $67.5 million compared to the prior year. The increase was driven by the growth of our portfolio resulting from acquisitions from SunEdison and unaffiliated third parties, which was partially offset by higher interest paid under long-term indebtedness.

Net Cash Used In Investing Activities

Net cash used in investing activities for the year ended December 31, 2016 was $49.9 million, which includes $45.9 million of cash paid to third parties for the construction of renewable energy facilities and other capital expenditures and $4.1 million of cash paid for third party acquisitions, net of cash and restricted cash acquired. Net cash used in investing activities for the year ended December 31, 2015 was $3.1 billion, which primarily consisted of $647.6 million of cash paid to third parties for the construction of renewable energy facilities and other capital expenditures and $2.4 billion of cash paid to third parties for acquisitions of renewable energy facilities, net of cash and restricted cash acquired.

Net Cash (Used In) Provided By Financing Activities

Net cash used in financing activities for the year ended December 31, 2016 was $187.2 million, which was primarily driven by $156.0 million of principal payments on non-recourse long-term debt and $103.0 million of repayments on revolving credit facility borrowings, partially offset by $86.7 million of net proceeds from non-recourse financing arrangements. Net cash provided by financing activities for the year ended December 31, 2015 was $3.2 billion, which consisted of $921.6 million of net proceeds from the issuance of Class A common stock, $946.0 million of proceeds from the issuance of the Senior Notes due 2023, $300.0 million of proceeds from the issuance of the Senior Notes due 2025, $655.0 million of net proceeds from revolving credit facility borrowings and $1.5 billion of net proceeds from non-recourse financing arrangements, partially offset by a $573.5 million repayment of our term loan, $517.6 million of principal payments on non-recourse long-term debt and dividend payments of $88.7 million.



68


Contractual Obligations and Commercial Commitments

We have a variety of contractual obligations and other commercial commitments that represent prospective cash requirements. The following table summarizes our outstanding contractual obligations and commercial commitments as of December 31, 2017:
 
 
Payment due by Period
Contractual Cash Obligations (in thousands)
 
20181
 
2019
 
2020
 
2021
 
2022
 
Thereafter
 
Total
Long-term debt (principal)2
 
$
152,745

 
$
91,404

 
$
96,087

 
$
99,278

 
$
591,032

 
$
2,496,183

 
$
3,526,729

Long-term debt (interest)3
 
182,366

 
176,967

 
172,218

 
166,866

 
159,470

 
598,538

 
1,456,425

Financing lease obligations4
 
9,852

 
19,108

 
9,218

 
9,130

 
5,700

 
62,779

 
115,787

Operating leases
 
14,940

 
14,545

 
14,713

 
14,922

 
15,062

 
248,175

 
322,357

Purchase obligations5
 
35,289

 
34,092

 
21,669

 
6,633

 
2,128

 
2,259

 
102,070

Brookfield MSA6
 
9,583

 
12,000

 
15,000

 
15,000

 
15,000

 
N/A7

 
66,583

Total contractual obligations
 
$
404,775

 
$
348,116

 
$
328,905

 
$
311,829

 
$
788,392

 
$
3,407,934

 
$
5,589,951

———
(1)
Includes $60.0 million of New Revolver indebtedness, of which we repaid $42.0 million with cash on hand in the first quarter of 2018.
(2)
Represents the contractual principal payment due dates for our long-term debt and does not reflect the reclassification of $200.3 million of long-term debt to current as a result of debt defaults under certain of our non-recourse financing arrangements (see Note 11. Long-term Debt to our consolidated financial statements for further discussion).
(3)
Includes fixed rate interest and variable rate interest using December 31, 2017 rates.
(4)
Represents the minimum lease payment due dates for our financing lease obligations and does not reflect the reclassification of $39.4 million of financing lease obligations to current as a result of debt defaults under certain of our non-recourse financing arrangements (see Note 11. Long-term Debt to our consolidated financial statements for further discussion).
(5)
Consists of contractual payments due for third party operation and maintenance services and asset management services.
(6)
Represents the fixed component of the base management fee owed pursuant to the master services agreement with Brookfield and certain of its affiliates for the management and administrative services to be provided by Brookfield and certain of its affiliates to the Company. See Note 20. Related Parties to our consolidated financial statements for further discussion.
(7)
We will be required to pay a base management fee with a fixed component of $3.75 million per quarter for each quarter in 2023 and beyond that Brookfield and certain of its affiliates provide management and administrative services to us. See Note 20. Related Parties to our consolidated financial statements for further discussion.

Off-Balance Sheet Arrangements

We enter into guarantee arrangements in the normal course of business to facilitate commercial transactions with third parties. See Note 19. Commitments and Contingencies to our consolidated financial statements included in this Annual Report on Form 10-K for additional discussion.

Critical Accounting Policies and Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires us to make estimates and assumptions in certain circumstances that affect amounts reported in our consolidated financial statements and related footnotes. In preparing these consolidated financial statements, we have made our best estimates of certain amounts included in the consolidated financial statements. Application of accounting policies and estimates, however, involves the exercise of judgment and use of assumptions as to future uncertainties and, as a result, actual results could differ from these estimates. In arriving at our critical accounting estimates, factors we consider include how accurate the estimate or assumptions have been in the past, how much the estimate or assumptions have changed and how reasonably likely such change may have a material impact. Our critical accounting policies are discussed below.

Business Combinations

The Company accounts for its business combinations by recognizing in the financial statements the identifiable assets acquired, the liabilities assumed, and any non-controlling interests in the acquiree at fair value at the acquisition date. The Company 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, acquisition costs related to business combinations are expensed as


69


incurred. Business combinations is a critical accounting policy as there are significant judgments involved in the allocation of acquisition cost.

When we acquire renewable energy facilities, we allocate the purchase price to (i) the acquired tangible assets and liabilities assumed, primarily consisting of land, plant, and long-term debt, (ii) the identified intangible assets and liabilities, primarily consisting of the value of favorable and unfavorable rate PPAs and REC agreements and the in-place value of market rate PPAs, (iii) non-controlling interests, and (iv) other working capital items based in each case on their fair values in accordance with ASC 805.

We generally engage independent appraisers to assist with the estimates and methodologies used such as a replacement cost approach, or an income approach or excess earnings approach. Factors considered by management in its analysis include considering current market conditions and costs to construct similar facilities. We also consider information obtained about each facility as a result of our pre-acquisition due diligence in estimating the fair value of the tangible and intangible assets and liabilities acquired or assumed. In estimating the fair value, we also establish estimates of energy production, current in-place and market power purchase rates, tax credit arrangements and operating and maintenance costs. A change in any of the assumptions above, which are subjective, could have a significant impact on the results of operations.

The allocation of the purchase price directly affects the following items in our consolidated financial statements:

The amount of purchase price allocated to the various tangible and intangible assets, liabilities and non-controlling interests on our balance sheet;
The amounts allocated to the value of favorable and unfavorable rate PPAs and REC agreements are amortized to revenue over the remaining non-cancelable terms of the respective arrangement. The amounts allocated to all other tangible assets and intangibles are amortized to depreciation or amortization expense, with the exception of favorable and unfavorable rate land leases and unfavorable rate O&M contracts which are amortized to cost of operations; and
The period of time over which tangible and intangible assets and liabilities are depreciated or amortized varies, and thus, changes in the amounts allocated to these assets and liabilities will have a direct impact on our results of operations.

The Company has not completed any material third party acquisitions since the fourth quarter of 2015.

Non-controlling Interests and Hypothetical Liquidation at Book Value (“HLBV”)

Non-controlling interests represent the portion of net assets in consolidated entities that are not owned by the Company and are reported as a component of equity in the consolidated balance sheets. Non-controlling interests in subsidiaries that are redeemable either at the option of the holder or at fixed and determinable prices at certain dates in the future are classified as redeemable non-controlling interests in subsidiaries between liabilities and stockholders' equity in the consolidated balance sheets. Redeemable non-controlling interests that are currently redeemable or redeemable after the passage of time are adjusted to their redemption value as changes occur. The Company applies the guidance in ASC 810-10 along with the SEC guidance in ASC 480-10-S99-3A in the valuation of redeemable non-controlling interests.

The Company has determined the allocation of economics between the controlling party and the third party for non-controlling interests does not correspond to ownership percentages for certain of its consolidated subsidiaries. In order to reflect the substantive profit sharing arrangements, the Company has determined that the appropriate methodology for determining the value of non-controlling interests is a balance sheet approach using the HLBV method. Under the HLBV method, the amounts reported as non-controlling interest on the consolidated balance sheets represent the amounts the third party investors could hypothetically receive at each balance sheet reporting date based on the liquidation provisions of the respective operating partnership agreements. HLBV assumes that the proceeds available for distribution are equivalent to the unadjusted, stand-alone net assets of each respective partnership, as determined under U.S. GAAP. The third party non-controlling interests in the consolidated statements of operations and statements of comprehensive loss are determined based on the difference in the carrying amounts of non-controlling interests on the consolidated balance sheets between reporting dates, adjusted for any capital transactions between the Company and third party investors that occurred during the respective period. 

Where, prior to the commencement of operating activities for a respective renewable energy facility, HLBV results in an immediate change in the carrying value of non-controlling interest on the consolidated balance sheet due to the recognition of ITCs or other adjustments as required by the U.S. Internal Revenue Code, the Company defers the recognition of the respective adjustments and recognizes the adjustments in non-controlling interest on the consolidated statement of operations on a straight-line basis over the expected life of the underlying assets giving rise to the respective difference. Similarly, where the Company has acquired a controlling interest in a partnership and there is a resulting difference between the initial fair value


70


of non-controlling interest and the value of non-controlling interest as measured using HLBV, the Company initially records non-controlling interest at fair value and amortizes the resulting difference over the remaining life of the underlying assets. 

Impairment of Renewable Energy Facilities and Intangibles

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. 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 as the difference between an asset's carrying amount and fair value. Fair values are determined by a variety of valuation methods, including appraisals, sales prices of similar assets and present value techniques. During the years ended December 31, 2017 and 2016, the Company recognized a $1.4 million and $19.0 million impairment charge, respectively, related to its portfolio of residential rooftop solar assets as reflected within impairment of renewable energy facilities in the consolidated statements of operations (see Note 4. Assets Held for Sale to our consolidated financial statements for further discussion). There were no impairments of renewable energy facilities or intangibles recognized during the year ended December 31, 2015. Impairment of long-lived assets that are held and used is considered a critical accounting policy as there are significant judgments involved in evaluating these potential indicators and events. Critical estimates primarily include long-term power and incentive prices in the post-contract periods.

Recently Issued Accounting Standards

See Note 2. Summary of Significant Accounting Policies to our consolidated financial statements included in this Annual Report on Form 10-K for disclosures concerning recently issued accounting standards. These disclosures are incorporated herein by reference.    

Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

We are exposed to several market risks in our normal business activities. Market risk is the potential loss that may result from market changes associated with our business or with an existing or forecasted financial or commodity transaction. The types of market risks we are exposed to are interest rate risk, foreign currency risk and commodity risk. We do not use derivative financial instruments for speculative purposes.

Interest Rate Risk

As of December 31, 2017, the estimated fair value of our debt was $3,702.5 million and the carrying value of our debt was $3,598.8 million. We estimate that a hypothetical 100 bps, or 1%, increase or decrease in market interest rates would have decreased or increased the fair value of our long-term debt by $89.9 million and $99.1 million, respectively.

As of December 31, 2017, our corporate-level debt amount consisted of the New Senior Notes due 2023 (fixed rate), the Senior Notes due 2025 (fixed rate), the Senior Notes due 2028 (fixed rate), the New Revolver (variable rate) and the New Term Loan (variable rate). We have not entered into any interest rate derivatives to swap our variable rate corporate-level debt to a fixed rate, and thus we are exposed to fluctuations in interest rate risk. A hypothetical increase or decrease in interest rates by 1% would have increased or decreased interest expense related to our New Revolver and New Term Loan, which only had outstanding borrowings during the fourth quarter of 2017, by $0.9 million for the year ended December 31, 2017.

As of December 31, 2017, our non-recourse permanent financing debt was at both fixed and variable rates. 60% of the $1,616.7 million balance had a fixed interest rate and the remaining 40% of the balance had a variable interest rate. We have entered into interest rate derivatives to swap a majority of our variable rate non-recourse debt to a fixed rate. Although we intend to use hedging strategies to mitigate our exposure to interest rate fluctuations, we may not hedge all of our interest rate risk and, to the extent we enter into interest rate hedges, our hedges may not necessarily have the same duration as the associated indebtedness. Our exposure to interest rate fluctuations will depend on the amount of indebtedness that bears interest at variable rates, the time at which the interest rate is adjusted, the amount of the adjustment, our ability to prepay or refinance variable rate indebtedness when fixed rate debt matures and needs to be refinanced and hedging strategies we may use to reduce the impact of any increases in rates. We estimate that a hypothetical 100 bps, or 1%, increase or decrease in our variable interest rates pertaining to interest rate swaps not designated as hedges would have increased or decreased our earnings by $0.7 million for the year ended December 31, 2017.


71



Foreign Currency Risk

During the year ended December 31, 2017, we generated operating revenues in the United States (including Puerto Rico), Canada, the United Kingdom and Chile, with our revenues being denominated in U.S. dollars, Canadian dollars and British pounds. The PPAs, operating and maintenance agreements, financing arrangements and other contractual arrangements relating to our current portfolio are denominated in U.S. dollars, Canadian dollars and British pounds.

We use currency forward contracts in certain instances to mitigate the financial market risks of fluctuations in foreign currency exchange rates. We manage our foreign currency exposures through the use of these currency forward contracts to reduce risks arising from the change in fair value of certain assets and liabilities denominated in Canadian dollars. The objective of these practices is to minimize the impact of foreign currency fluctuations on our operating results. We estimate that a hypothetical 100 bps, or 1%, increase or decrease in Canadian dollars would have increased or decreased our earnings by $0.1 million for the year ended December 31, 2017.

Commodity Risk

For certain of our wind power plants, we use long-term cash settled swap agreements to economically hedge commodity price variability inherent in wind electricity sales arrangements. If we sell electricity generated by our wind power plants to an independent system operator market and there is no PPA available, then we may enter into a commodity swap to hedge all or a portion of the estimated revenue stream. These price swap agreements require periodic settlements, in which we receive a fixed-price based on specified quantities of electricity and we pay the counterparty a variable market price based on the same specified quantity of electricity. We estimate that a hypothetical 1,000 bps, or 10%, increase or decrease in electricity sales prices pertaining to commodity swaps not designated as hedges would have decreased or increased our earnings by $2.9 million for the year ended December 31, 2017.

Counterparty Credit Risk

Credit risk relates to the risk of loss resulting from non-performance or non-payment by offtake counterparties under the terms of their contractual obligations, thereby impacting the amount and timing of expected cash flows. We monitor and manage credit risk through credit policies that include a credit approval process and the use of credit mitigation measures such as having a diversified portfolio of creditworthy offtake counterparties. As of December 31, 2017, on a weighted average basis (based on MW), our PPA counterparties had an investment grade credit rating. However, there are a limited number of offtake counterparties under offtake agreements in each region that we operate, and this concentration may impact the overall exposure to credit risk, either positively or negatively, in that the offtake counterparties may be similarly affected by changes in economic, industry or other conditions.

Item 8. Financial Statements and Supplementary Data.

The financial statements and schedules are listed in Part IV, Item 15. Exhibits, Financial Statement Schedules of this Annual report on Form 10-K and are incorporated by reference herein. Our selected quarterly financial data for each of the quarterly periods ended March 31, June 30, September 30 and December 31 in 2017 and 2016 are included in Note 23. Quarterly Financial Information (Unaudited) to our consolidated financial statements in this Annual report on Form 10-K.

Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure.

None.

Item 9A. Controls and Procedures.

We carried out an evaluation as of December 31, 2017, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended. Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures were not effective as of December 31, 2017, based on the material weaknesses discussed below in Management’s Report on Internal Control over Financial Reporting. These material weaknesses originated in prior years when SunEdison provided the systems and personnel for our financial reporting and control processes (such as information technology, enterprise resource management and accounting systems) under the management services agreement. Subsequent to the SunEdison Bankruptcy, the focus was on establishing an independent company and corresponding financial


72


and reporting processes. By doing so, we have removed our reliance on SunEdison personnel, financial systems and applications. The timing of this key business priority has delayed the Company in remediating the prior year’s material weaknesses and in having an effective control environment.

Notwithstanding such material weakness in internal control over financial reporting, our management concluded that our consolidated financial statements in this Annual Report on Form 10-K present fairly, in all material respects, the Company’s financial position, results of operations and cash flows as of the dates, and for the periods presented, in conformity with U.S. generally accepted accounting principles (“GAAP”).

Management’s Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP and includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with GAAP, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the Company’s assets that could have a material effect on the financial statements.

As of December 31, 2017, under the oversight of the principal executive and principal financial officers, and Board of Directors, management conducted an assessment of the effectiveness of our internal control over financial reporting based upon the framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control - Integrated Framework (2013) (“COSO 2013 Framework”). Based on management’s assessment using these criteria, they concluded that, as of December 31, 2017, there were material weaknesses in our internal control over financial reporting as further described below.

A material weakness is a deficiency or a combination of deficiencies in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement in our annual or interim financial statements will not be prevented or detected on a timely basis. As of December 31, 2017, we identified the following material weaknesses:

The Company did not maintain an effective control environment, and did not conduct an effective continuous risk assessment, information and communication process, and monitoring activities based on the following:

The Company did not have sufficient resources, including contractors, in place throughout the reporting period with the appropriate training and knowledge of internal controls over financial reporting in order to establish the Company’s financial reporting processes and information technology (“IT”) systems and to design, implement and operate an effective system of internal control over financial reporting.
The Company did not conduct continuous risk assessment and monitoring activities over financial reporting and IT systems to identify and analyze risks of financial misstatement due to error and/or fraud and to identify and assess necessary changes in GAAP and financial reporting processes and internal controls impacted by changes in the business, information systems, and transition of key personnel.
The Company did not have an effective information and communication process that ensured appropriate and accurate information was available to financial reporting personnel on a timely basis in order that they could fulfill their roles and responsibilities.

Accordingly, the Company did not establish appropriate control activities through policies and procedures to mitigate risk to the achievement of the Company’s financial reporting objectives, as follows:

The Company did not have effective IT general controls over all operating systems, databases, and IT applications supporting financial reporting. Process-level automated controls and manual controls that were dependent upon the information derived from IT systems were also determined to be ineffective. Additionally, the Company did not have effective end-user computing controls over spreadsheets used in financial reporting.
The Company did not have effective controls over the completeness, existence, and accuracy of revenues and deferred revenue and the completeness, existence, accuracy and valuation of accounts receivable.


73


The Company did not have effective reconciliation controls over the completeness, existence and accuracy of certain balance sheet accounts. Specifically, the reconciliation controls did not always operate timely and did not adequately investigate, resolve and correct reconciling items on a timely basis.
The Company did not have effective controls over the completeness, existence and accuracy of accounts payable, accrued expenses, and expenses. Specifically, the Company did not establish an effective accounts payable voucher and disbursement process and related internal controls in order to review and approve and accurately record expenditures on a timely basis.
The Company did not have effective controls over the completeness, existence and accuracy of renewable energy facilities, accumulated depreciation and depreciation, accretion and amortization expense.
The Company did not have effective process level and management review controls over the application of GAAP and accounting measurements related to certain significant accounts and non-routine transactions.
The Company did not have effective process-level and management review controls over manual financial reporting processes. Specifically, the Company did not have effective controls over the completeness and accuracy of information used in manual spreadsheets and the accuracy of those spreadsheet formulas.

These control deficiencies resulted in several material and immaterial misstatements to the preliminary consolidated financial statements that were corrected prior to the issuance of the consolidated financial statements. These control deficiencies create a reasonable possibility that a material misstatement to the consolidated financial statements will not be prevented or detected on a timely basis, and therefore we concluded that the deficiencies represent material weaknesses in the Company’s internal control over financial reporting and our internal control over financial reporting was not effective as of December 31, 2017.

Our independent registered public accounting firm, KPMG, LLP, who audited the consolidated financial statements included in this Annual Report, has expressed an adverse report on the operating effectiveness of the Company's internal control over financial reporting. KPMG LLP's report appears on page 78 of this Annual Report on Form 10-K.

Remediation Plan

We continue to strengthen our internal control over financial reporting. We are committed to ensuring that such controls are designed and operating effectively. With the closing of the Merger and Sponsorship Transaction with Brookfield on October 16, 2017, our Board of Directors and management have prioritized developing and implementing a remediation plan, taking the necessary actions to address the root causes that contributed to the material weaknesses identified and establishing and maintaining effective internal controls over financial reporting. Subsequent to the transaction with Brookfield, our Board implemented several actions, including revising our Board, Committee, and Internal Audit Charters, which enabled it to demonstrate that the effective oversight over financial reporting processes and internal controls is being properly exercised. A dedicated executive management team, consisting of experienced Brookfield executives was appointed and is playing an active role in oversight of the business and monitoring of the Company's internal control over financial reporting. Further, we implemented an effective annual process to ensure that all employees, as well as members of the Board, and outsourced service providers confirm their compliance with the Company’s Code of Business Conduct. We also implemented a whistleblower hotline which is available throughout the organization and through an external website. Information regarding the whistleblower hotline has been communicated to all employees. The Company has increased its communication and training to all employees and the Board regarding the Company’s ethical values and the requirement to comply with laws, rules, regulations, and the Company’s policies, including our Code of Conduct and Ethics. By taking these critical steps, two of the material weaknesses that existed as of December 31, 2016 were remediated in 2017. Furthermore, we remain focused on continuing to implement process and control improvements such as the following:

We have revised our organization structure and commenced hiring dedicated key employees, including senior management, with assigned responsibility and accountability for financial reporting processes and internal controls. Further, we will continue to provide ongoing GAAP and internal controls training for all the employees.
We are implementing an annual financial control risk assessment process as well as a regularly recurring fraud risk assessment process focused on identifying and analyzing risks of financial misstatement due to error and/or fraud, including management override of controls.
A senior internal audit resource was hired, and the internal audit function is being strengthened through increased interaction and engagement with the Brookfield internal audit team. A company-wide risk assessment has been completed and a risk-based internal audit plan is being developed that is responsive to the risks that were identified in the company-wide risk assessment. This risk-based internal audit plan will assist in monitoring the Company’s


74


adherence to its policies and procedures including policies and procedures related to any areas of concern or emphasis that the Board identifies as part of its oversight. We are also enhancing the business process documentation and management's self-assessment and testing for internal controls.
We are enhancing the information and communication processes to ensure the organization communicates information internally in a timely manner, including information regarding objectives, responsibilities and the functioning of internal controls over financial reporting. These enhancements include more rigorous analysis of the Company’s financial results versus its budgets and operating plans, more frequent discussion of significant business transactions and the impact of these transactions on the Company’s financial reporting, and improving communication to employees regarding their responsibilities for ensuring that effective internal controls are maintained.
We have established an information technology and other critical systems infrastructure, and are enhancing the information technology control framework to support all business applications and infrastructure. Remediation activities will formalize information technology processes to support larger IT initiatives that will address functionality limitations of current systems. 
We are developing a more efficient and effective financial close and reporting process through the implementation of a cloud-based SaaS accounting system. We intend to continually review this system for further enhancements and improvements.
Management is developing procedures and controls to obtain reliance on revenue systems and validating energy data used for revenue recognition.
We have implemented a cloud-based application to automate and standardize the account reconciliation process. We are validating controls over this application to ensure completeness, existence and accuracy of account balances on a timely basis.
We are developing policies and procedures for treatment and recognition of changes to renewable energy facilities account balances. This includes developing process level and review controls over accumulated depreciation and depreciation, accretion and amortization expense.
We are enhancing the management review controls over the application of GAAP and accounting measurements for significant accounts and transactions by adding resources with the required skills and assigned responsibility and accountability for performing an effective review.
Management review controls are being reassessed to provide the appropriate level of precision required to mitigate the potential for a material misstatement. In addition, we are enhancing the design and implementation of and supporting documentation over management review controls to make clear: (i) management’s expectations related to transactions that are subject to such controls; (ii) the level of precision and criteria used for investigation; and (iii) evidence that all outliers or exceptions that should have been identified are investigated and resolved. Lastly, management is reassessing and enhancing the controls over the utilization of manual spreadsheets and system generated reports.

We expect the implementation of our remediation plan will result in significant improvements to the overall internal control environment over financial reporting.

Changes in Internal Control over Financial Reporting

Other than changes described under Remediation Plan above, there have been no changes in the Company’s internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Securities Exchange Act of 1934, as amended) during the quarter ended December 31, 2017 that have materially affected, or are reasonably likely to materially affect the Company’s internal control over financial reporting.

Item 9B. Other Information.

None.



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PART III

Certain information required by Part III is omitted from this Form 10-K because the registrant will file with the U.S. Securities and Exchange Commission a definitive proxy statement pursuant to Regulation 14A in connection with the solicitation of proxies for the Company's Annual Meeting of Stockholders, or the 2018 Proxy Statement, within 120 days after the end of the fiscal year covered by this Form 10-K, and certain information included therein is incorporated herein by reference.

Item 10. Directors, Executive Officers and Corporate Governance.

The information required under this Item 10 is incorporated by reference to our 2018 Proxy Statement.    

Item 11. Executive Compensation.

The information required under this Item 11 is incorporated by reference to our 2018 Proxy Statement.

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

The information required under this Item 12 is incorporated by reference to our 2018 Proxy Statement.

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

The information required under this Item 13 is incorporated by reference to our 2018 Proxy Statement.

Item 14. Principal Accounting Fees and Services.

The information required under this Item 14 is incorporated by reference to our 2018 Proxy Statement.


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PART IV


Item 15. Exhibits, Financial Statement Schedules.

(a) The following documents are filed as a part of this report.

(1) Financial Statements:
 
 
Page
 
 
 
 
 
 
 
 

(2) Financial Statement Schedules:
The information required to be submitted in the Financial Statement Schedules for TerraForm Power, Inc. has either been shown in the financial statements or notes, or is not applicable or required under Regulation S-X; therefore, those schedules have been omitted.

(3) Exhibits:
See Exhibit Index submitted as a separate section of this Annual Report on Form 10-K.




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Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors
TerraForm Power, Inc.:

Opinion on Internal Control Over Financial Reporting
We have audited TerraForm Power, Inc. and subsidiaries’ (the Company) internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, because of the effect of the material weaknesses, described below, on the achievement of the objectives of the control criteria, the Company has not maintained effective internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 2017 and 2016, the related consolidated statements of operations, comprehensive loss, stockholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2017, and the related notes (collectively, the consolidated financial statements), and our report dated March 7, 2018 expressed an unqualified opinion on those consolidated financial statements.

A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the company’s annual or interim financial statements will not be prevented or detected on a timely basis. The following material weaknesses have been identified and included in management’s assessment:
The Company did not have sufficient resources, including contractors, in place throughout the reporting period with the appropriate training and knowledge of internal controls over financial reporting in order to establish the Company’s financial reporting processes and information technology (IT) systems and to design, implement and operate an effective system of internal control over financial reporting.
The Company did not conduct continuous risk assessment and monitoring activities over financial reporting and IT systems to identify and analyze risks of financial misstatement due to error and/or fraud and to identify and assess necessary changes in generally accepted accounting principles (GAAP) and financial reporting processes and internal controls impacted by changes in the business, information systems, and transition of key personnel.
The Company did not have an effective information and communication process that ensured appropriate and accurate information was available to financial reporting personnel on a timely basis in order that they could fulfill their roles and responsibilities.
The Company did not have effective IT general controls over all operating systems, databases, and IT applications supporting financial reporting. Process-level automated controls and manual controls that were dependent upon the information derived from IT systems were also determined to be ineffective. Additionally, the Company did not have effective end-user computing controls over spreadsheets used in financial reporting.
The Company did not have effective controls over the completeness, existence, and accuracy of revenues and deferred revenue and the completeness, existence, accuracy and valuation of accounts receivable.
The Company did not have effective reconciliation controls over the completeness, existence and accuracy of certain balance sheet accounts. Specifically, the reconciliation controls did not always operate timely and did not adequately investigate, resolve and correct reconciling items on a timely basis.
The Company did not have effective controls over the completeness, existence and accuracy of accounts payable, accrued expenses, and expenses. Specifically, the Company did not establish an effective accounts payable voucher and disbursement process and related internal controls in order to review and approve and accurately record expenditures on a timely basis.
The Company did not have effective controls over the completeness, existence and accuracy of renewable energy facilities, accumulated depreciation and depreciation, accretion and amortization expense.
The Company did not have effective process level and management review controls over the application of GAAP and accounting measurements related to certain significant accounts and non-routine transactions.
The Company did not have effective process-level and management review controls over manual financial reporting


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processes. Specifically, the Company did not have effective controls over the completeness and accuracy of information used in manual spreadsheets and the accuracy of those spreadsheet formulas.

The material weaknesses were considered in determining the nature, timing, and extent of audit tests applied in our audit of the 2017 consolidated financial statements, and this report does not affect our report on those consolidated financial statements.

Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ KPMG LLP

McLean, Virginia
March 7, 2018






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Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors
TerraForm Power, Inc.:

Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of TerraForm Power, Inc. and subsidiaries (the Company) as of December 31, 2017 and 2016, the related consolidated statements of operations, comprehensive loss, stockholders’ equity, and cash flows for each of the years in the three‑year period ended December 31, 2017, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for each of the years in the three‑year period ended December 31, 2017, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated March 7, 2018 expressed an adverse opinion on the effectiveness of the Company’s internal control over financial reporting.

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

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

/s/ KPMG LLP

We have served as the Company’s auditor since 2014.

McLean, Virginia
March 7, 2018



80


TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per share data)


 
Year Ended December 31,
 
2017
 
2016
 
2015
Operating revenues, net
$
610,471

 
$
654,556

 
$
469,506

Operating costs and expenses:
 
 
 
 
 
Cost of operations
150,733

 
113,302

 
70,468

Cost of operations - affiliate
17,601

 
26,683

 
19,915

General and administrative expenses
139,874

 
89,995

 
55,811

General and administrative expenses - affiliate
13,391

 
14,666

 
55,330

Acquisition and related costs

 
2,743

 
49,932

Acquisition and related costs - affiliate

 

 
5,846

Loss on prepaid warranty - affiliate

 

 
45,380

Goodwill impairment

 
55,874

 

Impairment of renewable energy facilities
1,429

 
18,951

 

Depreciation, accretion and amortization expense
246,720

 
243,365

 
161,310

Total operating costs and expenses
569,748

 
565,579

 
463,992

Operating income
40,723

 
88,977

 
5,514

Other expenses (income):
 
 
 
 
 
Interest expense, net
262,003

 
310,336

 
167,805

Loss on extinguishment of debt, net
81,099

 
1,079

 
16,156

Gain on sale of renewable energy facilities
(37,116
)
 

 

(Gain) loss on foreign currency exchange, net
(6,061
)
 
13,021

 
19,488

Loss on investments and receivables - affiliate
1,759

 
3,336

 
16,079

Other (income) expenses, net
(5,017
)
 
2,218

 
7,362

Total other expenses, net
296,667

 
329,990

 
226,890

Loss before income tax (benefit) expense
(255,944
)
 
(241,013
)
 
(221,376
)
Income tax (benefit) expense
(23,080
)
 
494

 
(13,241
)
Net loss
(232,864
)
 
(241,507
)
 
(208,135
)
Less: Pre-acquisition net income of renewable energy facilities acquired from SunEdison

 

 
1,610

Net loss excluding pre-acquisition net income of renewable energy facilities acquired from SunEdison
(232,864
)
 
(241,507
)
 
(209,745
)
Less: Net income attributable to redeemable non-controlling interests
10,884

 
18,365

 
8,512

Less: Net loss attributable to non-controlling interests
(79,559
)
 
(130,025
)
 
(138,371
)
Net loss attributable to Class A common stockholders
$
(164,189
)
 
$
(129,847
)
 
$
(79,886
)
 
 
 
 
 
 
Weighted average number of shares:
 
 
 
 
 
Class A common stock - Basic and diluted
103,866

 
90,815

 
65,883

Loss per share:
 
 
 
 
 
Class A common stock - Basic and diluted
$
(1.65
)
 
$
(1.47
)
 
$
(1.25
)


See accompanying notes to consolidated financial statements.

81


 
TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS
(In thousands)


 
Year Ended December 31,
 
2017
 
2016
 
2015
Net loss
$
(232,864
)
 
$
(241,507
)
 
$
(208,135
)
Other comprehensive income, net of tax:
 
 
 
 
 
Foreign currency translation adjustments:
 
 
 
 
 
Net unrealized gain (loss) arising during the period
10,300

 
(15,039
)
 
(18,446
)
Reclassification of net realized loss into earnings1
14,741

 

 

Hedging activities:
 
 
 
 
 
Net unrealized gain (loss) arising during the period
17,612

 
(86
)
 
26,913

Reclassification of net realized (gain) loss into earnings2
(2,247
)
 
15,967

 
4,663

Other comprehensive income, net of tax
40,406

 
842

 
13,130

Total comprehensive loss
(192,458
)
 
(240,665
)
 
(195,005
)
Less: Pre-acquisition net income of renewable energy facilities acquired from SunEdison

 

 
1,610

Less: Pre-acquisition other comprehensive income of renewable energy facilities acquired from SunEdison

 

 
40,016

Comprehensive loss excluding pre-acquisition comprehensive income of renewable energy facilities acquired from SunEdison
(192,458
)
 
(240,665
)
 
(236,631
)
Less comprehensive income (loss) attributable to non-controlling interests:
 
 
 
 
 
Net income attributable to redeemable non-controlling interests
10,884

 
18,365

 
8,512

Net loss attributable to non-controlling interests
(79,559
)
 
(130,025
)
 
(138,371
)
Foreign currency translation adjustments
8,665

 
(4,639
)
 
(7,862
)
Hedging activities
5,992

 
5,469

 
(3,545
)
Comprehensive loss attributable to non-controlling interests
(54,018
)
 
(110,830
)
 
(141,266
)
Comprehensive loss attributable to Class A common stockholders
$
(138,440
)
 
$
(129,835
)

$
(95,365
)
———
(1)
Represents reclassification of the accumulated foreign currency translation loss for substantially all of the Company's portfolio of solar power plants located in the United Kingdom, as the Company's sale of these facilities closed in the second quarter of 2017 as discussed in Note 4. Assets Held for Sale. The pre-tax amount of $23.6 million was recognized within gain on sale of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2017.
(2)
Includes $16.9 million loss reclassification for the year ended December 31, 2016 that occurred subsequent to the Company's discontinuation of hedge accounting for interest rate swaps pertaining to variable rate non-recourse debt for substantially all of the Company's portfolio of solar power plants located in the United Kingdom as discussed in Note 13. Derivatives. As discussed above, the Company's sale of these facilities closed in the second quarter of 2017.


See accompanying notes to consolidated financial statements.

82


 
TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(In thousands, except share and per share data)


 
As of December 31,
 
2017
 
2016
Assets
 
 
 
Current assets:
 
 
 
Cash and cash equivalents
$
128,087

 
$
565,333

Restricted cash
54,006

 
114,950

Accounts receivable, net
89,680

 
89,461

Prepaid expenses and other current assets
65,393

 
61,749

Due from affiliate
4,370

 

Assets held for sale

 
61,523

Total current assets
341,536

 
893,016

 
 
 
 
Renewable energy facilities, net, including consolidated variable interest entities of $3,273,848 and $3,434,549 in 2017 and 2016, respectively
4,801,925

 
4,993,251

Intangible assets, net, including consolidated variable interest entities of $823,629 and $875,095 in 2017 and 2016, respectively
1,077,786

 
1,142,112

Restricted cash
42,694

 
2,554

Other assets
123,080

 
122,661

Non-current assets held for sale

 
552,271

Total assets
$
6,387,021

 
$
7,705,865

 
 
 
 

See accompanying notes to consolidated financial statements.

83



TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(In thousands, except share and per share data)
(CONTINUED)


 
As of December 31,
 
2017
 
2016
Liabilities, Redeemable Non-controlling Interests and Stockholders' Equity
 
 
 
Current liabilities:
 
 
 
Current portion of long-term debt and financing lease obligations, including consolidated variable interest entities of $84,691 and $594,442 in 2017 and 2016, respectively
$
403,488

 
$
2,212,968

Accounts payable, accrued expenses and other current liabilities
88,538

 
125,596

Deferred revenue
17,859

 
18,179

Due to affiliates, net
3,968

 
16,692

Liabilities related to assets held for sale

 
21,798

Total current liabilities
513,853

 
2,395,233

Long-term debt and financing lease obligations, less current portion, including consolidated variable interest entities of $833,388 and $375,726 in 2017 and 2016, respectively
3,195,312

 
1,737,946

Deferred revenue, less current portion
38,074

 
55,793

Deferred income taxes
18,636

 
27,723

Asset retirement obligations, including consolidated variable interest entities of $97,467 and $92,213 in 2017 and 2016, respectively
154,515

 
148,575

Other long-term liabilities
37,923

 
31,470

Non-current liabilities related to assets held for sale

 
410,759

Total liabilities
3,958,313

 
4,807,499

 
 
 
 
Redeemable non-controlling interests
58,340

 
180,367

Stockholders' equity:
 
 
 
Class A common stock, $0.01 par value per share, 1,200,000,000 shares authorized in 2017, 148,586,447 and 92,476,776 shares issued in 2017 and 2016, respectively, and 148,086,027 and 92,223,089 shares outstanding in 2017 and 2016, respectively
1,486

 
920

Class B common stock, $0.01 par value per share, no shares authorized or issued in 2017, 48,202,310 shares issued and outstanding in 2016

 
482

Additional paid-in capital
1,866,206

 
1,467,108

Accumulated deficit
(398,629
)
 
(234,440
)
Accumulated other comprehensive income
48,018

 
22,912

Treasury stock, 500,420 and 253,687 shares in 2017 and 2016, respectively
(6,712
)
 
(4,025
)
Total TerraForm Power, Inc. stockholders' equity
1,510,369

 
1,252,957

Non-controlling interests
859,999

 
1,465,042

Total stockholders' equity
2,370,368

 
2,717,999

Total liabilities, redeemable non-controlling interests and stockholders' equity
$
6,387,021

 
$
7,705,865


See accompanying notes to consolidated financial statements.

84


TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(In thousands)


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Accumulated Other Comprehensive (Loss) Income
 
 
 
 
 
 
 
Non-controlling Interests
 
 
 
Class A Common Stock Issued
 
Class B Common Stock Issued
 
Class B1 Common Stock Issued
 
Additional Paid-in Capital
 
Accumulated Deficit
 
 
Common Stock Held in Treasury
 
 
 
 
 
Accumulated Deficit
 
Accumulated Other Comprehensive Loss
 
 
 
Total Equity
 
Shares
 
Amount
 
Shares
 
Amount
 
Shares
 
Amount
 
 
 
 
Shares
 
Amount
 
Total
 
Capital
 
 
 
Total
 
Balance as of December 31, 2014
42,218

 
$
387

 
64,526

 
$
645

 
5,840

 
$
58

 
$
498,256

 
$
(26,317
)
 
$
(1,637
)
 

 
$

 
$
471,392

 
$
1,092,809

 
$
(44,451
)
 
$
(3,829
)
 
$
1,044,529

 
$
1,515,921

Issuance of Class A common stock, net of issuance costs
31,912

 
318

 
(4,162
)
 
(41
)
 

 

 
921,333

 

 

 

 

 
921,610

 

 

 

 

 
921,610

Riverstone exchange
5,840

 
58

 

 

 
(5,840
)
 
(58
)
 

 

 

 

 

 

 

 

 

 

 

Stock-based compensation
(236
)
 
21

 

 

 

 

 
22,622

 

 

 
(122
)
 
(2,436
)
 
20,207

 

 

 

 

 
20,207

Net loss

 

 

 

 

 

 

 
(79,886
)
 

 

 

 
(79,886
)
 

 
(138,371
)
 

 
(138,371
)
 
(218,257
)
Pre-acquisition net income of renewable energy facilities acquired from SunEdison

 

 

 

 

 

 

 
1,610

 

 

 

 
1,610

 

 

 

 

 
1,610

Dividends

 

 

 

 

 

 
(88,705
)
 

 

 

 

 
(88,705
)
 

 

 

 

 
(88,705
)
Consolidation of non-controlling interests in acquired renewable energy facilities

 

 

 

 

 

 

 

 

 

 

 

 
413,014

 

 

 
413,014

 
413,014

Repurchase of non-controlling interest in renewable energy facility

 

 

 

 

 

 

 

 

 

 

 

 
(54,694
)
 

 

 
(54,694
)
 
(54,694
)
Net SunEdison investment

 

 

 

 

 

 
84,288

 

 

 

 

 
84,288

 
69,113

 

 

 
69,113

 
153,401

Other comprehensive loss

 

 

 

 

 

 

 

 
(15,479
)
 

 

 
(15,479
)
 

 

 
(11,407
)
 
(11,407
)
 
(26,886
)
Pre-acquisition other comprehensive income of renewable energy facilities acquired from SunEdison

 

 

 

 

 

 

 

 
40,016

 

 

 
40,016

 

 

 

 

 
40,016

Sale of membership interests and contributions from non-controlling interests in renewable energy facilities

 

 

 

 

 

 

 

 

 

 

 

 
346,704

 

 

 
346,704

 
346,704

Distributions to non-controlling interests

 

 

 

 

 

 

 

 

 

 

 

 
(83,672
)
 

 

 
(83,672
)
 
(83,672
)
Equity reallocation

 

 

 

 

 

 
(170,310
)
 

 

 

 

 
(170,310
)
 
170,310

 

 

 
170,310

 

Balance as of December 31, 2015
79,734

 
$
784

 
60,364

 
$
604

 

 
$

 
$
1,267,484

 
$
(104,593
)
 
$
22,900

 
(122
)
 
$
(2,436
)
 
$
1,184,743

 
$
1,953,584

 
$
(182,822
)
 
$
(15,236
)
 
$
1,755,526

 
$
2,940,269




See accompanying notes to consolidated financial statements.

85


TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(In thousands)
(CONTINUED)



 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Non-controlling Interests
 
 
 
Class A Common Stock Issued
 
Class B Common Stock Issued
 
Additional Paid-in Capital
 
Accumulated Deficit
 
Accumulated Other Comprehensive Income
 
Common Stock Held in Treasury
 
 
 
 
 
Accumulated Deficit
 
Accumulated Other Comprehensive (Loss) Income
 
 
 
Total Equity
 
Shares
 
Amount
 
Shares
 
Amount
 
 
 
 
Shares
 
Amount
 
Total
 
Capital
 
 
 
Total
 
Balance as of December 31, 2015
79,734

 
$
784

 
60,364

 
$
604

 
$
1,267,484

 
$
(104,593
)
 
$
22,900

 
(122
)
 
$
(2,436
)
 
$
1,184,743

 
$
1,953,584

 
$
(182,822
)
 
$
(15,236
)
 
$
1,755,526

 
$
2,940,269

SunEdison exchange
12,162

 
122

 
(12,162
)
 
(122
)
 
181,045

 

 

 

 

 
181,045

 
(181,045
)
 

 

 
(181,045
)
 

Stock-based compensation
581

 
14

 

 

 
6,729

 

 

 
(132
)
 
(1,589
)
 
5,154

 

 

 

 

 
5,154

Net loss

 

 

 

 

 
(129,847
)
 

 

 

 
(129,847
)
 

 
(130,025
)
 

 
(130,025
)
 
(259,872
)
Acquisition accounting adjustment to non-controlling interest in acquired renewable energy facility

 

 

 

 

 

 

 

 

 

 
8,000

 

 

 
8,000

 
8,000

Repurchase of non-controlling interest in renewable energy facility

 

 

 

 

 

 

 

 

 

 
(486
)
 

 

 
(486
)
 
(486
)
Net SunEdison investment

 

 

 

 
16,372

 

 

 

 

 
16,372

 
9,028

 

 

 
9,028

 
25,400

Other comprehensive income

 

 

 

 

 

 
12

 

 

 
12

 

 

 
830

 
830

 
842

Sale of membership interests and contributions from non-controlling interests in renewable energy facilities

 

 

 

 

 

 

 

 

 

 
15,674

 

 

 
15,674

 
15,674

Distributions to non-controlling interests in renewable energy facilities

 

 

 

 

 

 

 

 

 

 
(13,020
)
 

 

 
(13,020
)
 
(13,020
)
Accretion of redeemable non-controlling interest

 

 

 

 
(3,962
)
 

 

 

 

 
(3,962
)
 

 

 

 

 
(3,962
)
Equity reallocation

 

 

 

 
(560
)
 

 

 

 

 
(560
)
 
560

 

 

 
560

 

Balance as of December 31, 2016
92,477

 
$
920

 
48,202

 
$
482


$
1,467,108

 
$
(234,440
)
 
$
22,912

 
(254
)
 
$
(4,025
)
 
$
1,252,957


$
1,792,295

 
$
(312,847
)
 
$
(14,406
)
 
$
1,465,042

 
$
2,717,999

Net SunEdison investment

 

 

 

 
7,019

 

 

 

 

 
7,019

 
2,749

 

 

 
2,749

 
9,768

Equity reallocation

 

 

 

 
8,780

 

 

 

 

 
8,780

 
(8,780
)
 

 

 
(8,780
)
 

SunEdison exchange
48,202

 
482

 
(48,202
)
 
(482
)
 
641,452

 

 
(643
)
 

 

 
640,809

 
(835,662
)
 
194,210

 
643

 
(640,809
)
 

Issuance of Class A common stock to SunEdison
6,493

 
65

 

 

 
(65
)
 

 

 

 

 

 

 

 

 

 

Write-off of payables to SunEdison

 

 

 

 
15,677

 

 

 

 

 
15,677

 

 

 

 

 
15,677

Stock-based compensation
1,414

 
19

 

 

 
14,689

 

 

 
(246
)
 
(2,687
)
 
12,021

 

 

 

 

 
12,021

Net loss

 

 

 

 

 
(164,189
)
 

 

 

 
(164,189
)
 

 
(79,559
)
 

 
(79,559
)
 
(243,748
)
Special Dividend payment

 

 

 

 
(285,497
)
 

 

 

 

 
(285,497
)
 

 

 

 

 
(285,497
)
Other comprehensive income

 

 

 

 

 

 
25,749

 

 

 
25,749

 

 

 
14,657

 
14,657

 
40,406

Sale of membership interests and contributions from non-controlling interests in renewable energy facilities

 

 

 

 

 

 

 

 

 

 
6,935

 

 

 
6,935

 
6,935

Distributions to non-controlling interests in renewable energy facilities

 

 

 

 

 

 

 

 

 

 
(23,345
)
 

 

 
(23,345
)
 
(23,345
)
Deconsolidation of non-controlling interest in renewable energy facility

 

 

 

 

 

 

 

 

 

 
(8,713
)
 

 

 
(8,713
)
 
(8,713
)
Accretion of redeemable non-controlling interest

 

 

 

 
(6,729
)
 

 

 

 

 
(6,729
)
 

 

 

 

 
(6,729
)
Reclassification of Invenergy Wind Interest from redeemable non-controlling interests to non-controlling interests

 

 

 

 

 

 

 

 

 

 
131,822

 

 

 
131,822

 
131,822

Other

 

 

 

 
3,772

 

 

 

 

 
3,772

 

 

 

 

 
3,772

Balance as of December 31, 2017
148,586

 
$
1,486

 

 
$

 
$
1,866,206

 
$
(398,629
)
 
$
48,018

 
(500
)
 
$
(6,712
)
 
$
1,510,369

 
$
1,057,301

 
$
(198,196
)
 
$
894

 
$
859,999

 
$
2,370,368


See accompanying notes to consolidated financial statements.

86



TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)

 
Year Ended December 31,
2017
 
2016
 
2015
Cash flows from operating activities:
 
 
 
 
 
Net loss
$
(232,864
)
 
$
(241,507
)
 
$
(208,135
)
Adjustments to reconcile net loss to net cash provided by operating activities:
 
 
 
 
 
Depreciation, accretion and amortization expense
246,720

 
243,365

 
161,310

Amortization of favorable and unfavorable rate revenue contracts, net
39,576

 
40,219

 
5,304

Loss on extinguishment of debt, net
81,099

 
1,079

 
16,156

Gain on sale of renewable energy facilities
(37,116
)
 

 

Goodwill impairment

 
55,874

 

Impairment of renewable energy facilities
1,429

 
18,951

 

Amortization of deferred financing costs and debt discounts
23,729

 
24,160

 
27,028

Unrealized loss on U.K. interest rate swaps
2,425

 
24,209

 

Unrealized loss on commodity contract derivatives, net
6,847

 
11,773

 
1,413

Recognition of deferred revenue
(18,238
)
 
(16,527
)
 
(9,909
)
Stock-based compensation expense
16,778

 
6,059

 
13,125

Unrealized (gain) loss on foreign currency exchange, net
(5,583
)
 
15,795

 
22,343

Loss on prepaid warranty - affiliate

 

 
45,380

Loss on investments and receivables - affiliate
1,759

 
3,336

 
16,079

Deferred taxes
(23,350
)
 
375

 
(13,497
)
Other, net
(1,166
)
 
2,542

 
9,395

Changes in assets and liabilities:
 
 
 
 
 
Accounts receivable
(2,939
)
 
3,112

 
(11,272
)
Prepaid expenses and other current assets
803

 
(8,585
)
 
12,189

Accounts payable, accrued expenses and other current liabilities
(42,736
)
 
(1,156
)
 
19,887

Due to affiliates, net
3,968

 

 

Deferred revenue
199

 
4,803

 
19,383

Other, net
5,857

 
3,932

 
(1,919
)
Net cash provided by operating activities
67,197

 
191,809

 
124,260

Cash flows from investing activities:
 
 
 
 
 
Cash paid to third parties for renewable energy facility construction and other capital expenditures
(8,392
)
 
(45,869
)
 
(647,561
)
Proceeds from sale of renewable energy facilities, net of cash and restricted cash disposed
183,235

 

 

Proceeds from renewable energy state rebate
15,542

 

 

Proceeds from reimbursable interconnection costs
10,137

 

 

Acquisitions of renewable energy facilities from third parties, net of cash and restricted cash acquired

 
(4,064
)
 
(2,432,226
)
Due to SunEdison, net

 

 
(26,153
)
Other investing activities
5,750

 

 
(8,400
)
Net cash provided by (used in) investing activities
$
206,272

 
$
(49,933
)
 
$
(3,114,340
)

See accompanying notes to consolidated financial statements.

87



TERRAFORM POWER, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(CONTINUED)

 
Year Ended December 31,
2017
 
2016
 
2015
Cash flows from financing activities:
 
 
 
 
 
Proceeds from issuance of Class A common stock
$

 
$

 
$
921,610

Proceeds from Senior Notes due 2023

 

 
945,962

Repayment of Senior Notes due 2023
(950,000
)
 

 

Proceeds from New Senior Notes due 2023
494,985

 

 

Proceeds from Senior Notes due 2025

 

 
300,000

Proceeds from Senior Notes due 2028
692,979

 

 

Proceeds from New Term Loan
344,650

 

 

Repayment of Term Loan

 

 
(573,500
)
Revolver draws

 

 
890,000

Revolver repayments
(552,000
)
 
(103,000
)
 
(235,000
)
New Revolver draws
265,000

 

 

New Revolver repayments
(205,000
)
 

 

Borrowings of non-recourse long-term debt
79,835

 
86,662

 
1,450,707

Principal payments and prepayments on non-recourse long-term debt
(569,463
)
 
(156,042
)
 
(517,600
)
Debt prepayment premium
(50,712
)
 

 
(6,412
)
Debt financing fees
(29,972
)
 
(17,436
)
 
(59,672
)
Sale of membership interests and contributions from non-controlling interests in renewable energy facilities
6,935

 
16,685

 
349,736

Repurchase of non-controlling interests in renewable energy facilities

 
(486
)
 
(63,198
)
Distributions to non-controlling interests
(31,163
)
 
(23,784
)
 
(28,145
)
Distributions to SunEdison

 

 
(58,291
)
Net SunEdison investment
7,694

 
42,463

 
149,936

Due to affiliates, net
(8,869
)
 
(32,256
)
 
(138,923
)
Payment of dividends
(285,497
)
 

 
(88,705
)
Other financing activities
1,085

 

 

Net cash (used in) provided by financing activities
(789,513
)
 
(187,194
)
 
3,238,505

Net (decrease) increase in cash, cash equivalents and restricted cash
(516,044
)
 
(45,318
)
 
248,425

Net change in cash, cash equivalents and restricted cash classified within assets held for sale
54,806

 
(54,806
)
 

Effect of exchange rate changes on cash, cash equivalents and restricted cash
3,188

 
(10,072
)
 
(4,946
)
Cash, cash equivalents and restricted cash at beginning of period
682,837

 
793,033

 
549,554

Cash, cash equivalents and restricted cash at end of period
$
224,787

 
$
682,837

 
$
793,033

 
 
 
 
 
 
Supplemental Disclosures:
 
 
 
 
 
Cash paid for interest, net of amounts capitalized
$
260,685

 
$
257,269

 
$
114,452

Cash paid for income taxes

 

 

Schedule of non-cash activities:
 
 
 
 
 
Additions to renewable energy facilities in accounts payable, accrued expenses and other current liabilities
$
1,622

 
$

 
$
6,034

Loss on disposal of wind power plant components
5,828

 

 

Write-off of payables to SunEdison to additional paid-in capital
15,677

 

 

Additions of asset retirement obligation (ARO) assets and liabilities

 
2,132

 
52,181

Revisions in estimates for asset retirement obligations

 
(7,920
)
 

Adjustment to ARO related to change in accretion period

 
(22,204
)
 

ARO assets and obligations from acquisitions

 
136

 
74,293

Long-term debt assumed in connection with acquisitions

 

 
667,384


See accompanying notes to consolidated financial statements.

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TERRAFORM POWER, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Dollar amounts in thousands, except per share data, unless otherwise noted)


1. NATURE OF OPERATIONS AND BASIS OF PRESENTATION

Nature of Operations

Prior to the consummation of the Merger (as defined below) on October 16, 2017, TerraForm Power, Inc. (“TerraForm Power”) and its subsidiaries (together with TerraForm Power, the “Company”) were controlled affiliates of SunEdison, Inc. (together with its consolidated subsidiaries excluding the Company and TerraForm Global, Inc. and its subsidiaries, “SunEdison”). As a result of the consummation of the Merger, a change of control of TerraForm Power occurred, and Orion US Holdings 1 L.P. (“Orion Holdings”), which is an affiliate of Brookfield Asset Management Inc. (“Brookfield”), now holds 51% of the voting securities of TerraForm Power. As a result of the Merger closing, TerraForm Power is no longer a controlled affiliate of SunEdison, Inc. and is now a controlled affiliate of Brookfield.

TerraForm Power is a holding company and its only material asset is an equity interest in TerraForm Power, LLC (“Terra LLC”), which through its subsidiaries owns and operates renewable energy facilities that have long-term contractual arrangements to sell the electricity generated by these facilities to third parties. The related green energy certificates, ancillary services and other environmental attributes generated by these facilities are also sold to third parties. TerraForm Power is the managing member of Terra LLC and operates, controls and consolidates the business affairs of Terra LLC. The Company is sponsored by Brookfield and has an objective to acquire operating solar and wind assets in North America and Western Europe.

The Consummation of the Brookfield Sponsorship Transaction and of the Settlement with SunEdison

On April 21, 2016, SunEdison, Inc. and certain of its domestic and international subsidiaries (the “SunEdison Debtors”) voluntarily filed for protection under Chapter 11 of the U.S. Bankruptcy Code (the “SunEdison Bankruptcy”). In response to SunEdison’s financial and operating difficulties, the Company initiated a process for the exploration and evaluation of potential strategic alternatives for the Company, including potential transactions to secure a new sponsor or sell the Company, and a process to settle claims with SunEdison. This process resulted in the Company's entry into a definitive merger and sponsorship transaction agreement (the “Merger Agreement”) on March 6, 2017 with Orion Holdings and BRE TERP Holdings Inc. (“Merger Sub”), a wholly-owned subsidiary of Orion Holdings, which are affiliates of Brookfield. At the same time, the Company and SunEdison also entered into a settlement agreement (the “Settlement Agreement”) and a voting and support agreement (the “Voting and Support Agreement”), among other things, to facilitate the closing of the merger transaction and the settlement of claims between the Company and SunEdison.

On October 6, 2017, the Merger Agreement was approved by the holders of a majority of the outstanding Class A shares of TerraForm Power, excluding SunEdison, Orion Holdings, any of their respective affiliates or any person with whom any of them has formed (and not terminated) a “group” (as such term is defined in the Securities Exchange Act of 1934, as amended) and by the holders of a majority of the total voting power of the outstanding shares of the Company's common stock entitled to vote on the transaction. With these votes, all conditions to the merger transaction contemplated by the Merger Agreement were satisfied. On October 16, 2017, Merger Sub merged with and into TerraForm Power (the “Merger”), with TerraForm Power continuing as the surviving corporation in the Merger. Immediately following the consummation of the Merger, there were 148,086,027 Class A shares of TerraForm Power outstanding (which excludes 138,402 Class A shares that were issued and held in treasury to pay applicable employee tax withholdings for restricted stock units (“RSUs”) held by employees that vested upon the consummation of the Merger) and Orion Holdings holds 51% of such shares. In addition, pursuant to the Merger Agreement, at or prior to the effective time of the Merger, the Company and Orion Holdings (or one of its affiliates), among other parties, entered into a suite of agreements providing for sponsorship arrangements, including a master services agreement, relationship agreement, governance agreement and a sponsor line of credit (the “Sponsorship Transaction”), as are more fully described in Note 20. Related Parties and Note 11. Long-term Debt.

Immediately prior to the effective time of the Merger, pursuant to the Settlement Agreement, SunEdison exchanged all of the Class B units held by SunEdison or any of its controlled affiliates in Terra LLC for 48,202,310 Class A shares of TerraForm Power, and as a result of this exchange, all shares of Class B common stock of TerraForm Power held by SunEdison or any of its controlled affiliates were automatically redeemed and retired. Pursuant to the Settlement Agreement, immediately following this exchange, the Company issued to SunEdison additional Class A shares such that immediately prior to the effective time of the Merger, SunEdison and certain of its affiliates held an aggregate number of Class A shares equal to 36.9% of the Company’s fully diluted share count (which was subject to proration based on the Merger consideration election results


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as discussed in Note 15. Stockholders' Equity). SunEdison and certain of its affiliates also transferred all of the outstanding incentive distribution rights (“IDRs”) of Terra LLC held by SunEdison or certain of its affiliates to BRE Delaware, Inc. (the “Brookfield IDR Holder”) at the effective time of the Merger. Under the Settlement Agreement, upon the consummation of the Merger, all agreements between the Company and the SunEdison Debtors were deemed rejected, subject to certain limited exceptions, without further liability, claims or damages on the part of the Company. The settlements, mutual release and certain other terms and conditions of the Settlement Agreement also became effective upon the consummation of the Merger. Refer to Note 20. Related Parties for further discussion.

Going Concern

In its Form 10-K for the year ended December 31, 2016 and its Forms 10-Q for each of the quarters ended March 31, 2017 and June 30, 2017, the Company disclosed there was substantial doubt about its ability to continue as a going concern. While the financial statements accompanying those filings and the accompanying consolidated financial statements were prepared on a going concern basis, the matters disclosed in those filings raised substantial doubt about the Company’s ability to continue as a going concern as a result of the SunEdison Bankruptcy and the related impacts on the Company, including the Company’s historic reliance on SunEdison, defaults under project-level financing arrangements and the potential for creditors or other stakeholders of SunEdison to petition the court to substantively consolidate the Company’s assets and liabilities into the SunEdison bankruptcy estate.

Since the date of the SunEdison Bankruptcy, the Company has implemented significant measures to mitigate its impact on the Company. Consistent with the disclosures in the Company's Form 10-Q for the quarter ended September 30, 2017, management no longer believes the SunEdison Bankruptcy and the related impacts raise substantial doubt about the Company’s ability to continue as a going concern for the following reasons:

The Company has eliminated its reliance on SunEdison by transitioning the asset management, operations and maintenance of its renewable energy facilities in-house or to third parties, by hiring directly its own employees and contractors and by establishing its own information technology systems. As a result, management believes they are in a position to operate the business of the Company on a stand-alone basis under Brookfield sponsorship.
The Company has cured or obtained waivers with respect to substantially all of its project-level financing arrangements that were in default during the course of 2016 and 2017 as a result of the SunEdison Bankruptcy and delays in delivering financial statements and other required deliverables. The amount of restricted cash associated with the limited number of defaults that persist that cannot be distributed from the projects as of the date of the issuance of these financial statements is $11.3 million and is not needed for the Company to meet its cash flow needs. The Company expects to obtain waivers for these remaining defaults in the near-term and does not expect these defaults to affect its ability to meet its liquidity requirements and meet corporate credit facility covenants.
Finally, during the course of the SunEdison Bankruptcy there was a risk that an interested party in the SunEdison Bankruptcy could request that the assets and liabilities of the Company be substantively consolidated with SunEdison. As a result of SunEdison's emergence from bankruptcy in December of 2017, there is no longer any risk that the United States Bankruptcy Court for the Southern District of New York (the “Bankruptcy Court”) would order substantive consolidation of the Company with the SunEdison Debtors.

Basis of Presentation

When the Company was a controlled affiliate of SunEdison, it was required to recast historical financial statements when renewable energy facilities were acquired from SunEdison. The recast reflected the assets and liabilities, results of operations and cash flows of the acquired renewable energy facilities for the period the facilities were owned by SunEdison, which was in accordance with applicable rules governing transactions between entities under common control. The Company has not acquired any renewable energy facilities from SunEdison since the first quarter of 2016, and as a result, there have been no corresponding changes to the Company's previously reported consolidated financial statements included in the Company's Form 10-K for the year ended December 31, 2016. Subsequent to the consummation of the Merger and change of control that occurred in October 2017, the Company has not acquired any renewable energy facilities from Brookfield or any of its affiliates.

The accompanying consolidated financial statements represent the results of TerraForm Power, which consolidates Terra LLC through its controlling interest.


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The Company has elected to not push-down the application of the acquisition method of accounting to its consolidated financial statements following the consummation of the Merger and the change of control that occurred.
    
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates

In preparing the consolidated financial statements, the Company used estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the financial statements. Such estimates also affect the reported amounts of revenues, expenses and cash flows during the reporting period. To the extent there are material differences between the estimates and actual results, the Company's future results of operations would be affected.

Principles of Consolidation

The accompanying consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“U.S. GAAP”). They include the results of wholly owned and partially owned subsidiaries in which the Company has a controlling interest with all significant intercompany accounts and transactions eliminated.

Variable Interest Entities

The Company assesses entities for consolidation in accordance with ASC 810. The Company consolidates variable interest entities (“VIEs”) in renewable energy facilities when determined to be the primary beneficiary. VIEs are entities that lack one or more of the characteristics of a voting interest entity (“VOE”). The Company has a controlling financial interest in a VIE when its variable interest or interests provide it with (i) the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and (ii) the obligation to absorb losses of the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE.

VOEs are entities in which (i) the total equity investment at risk is sufficient to enable the entity to finance its activities independently and (ii) the equity holders have the power to direct the activities of the entity that most significantly impact its economic performance, the obligation to absorb the losses of the entity and the right to receive the residual returns of the entity. The usual condition for a controlling financial interest in a voting interest entity is ownership of a majority voting interest. If the Company has a majority voting interest in a voting interest entity, the entity is consolidated.

For the Company's consolidated VIEs, the Company has presented on its consolidated balance sheets, to the extent material, the assets of its consolidated VIEs that can only be used to settle specific obligations of the consolidated VIE, and the liabilities of its consolidated VIEs for which creditors do not have recourse to the Company's general assets outside of the VIE.

Cash and Cash Equivalents

Cash and cash equivalents include all cash balances and money market funds with original maturity periods of three months or less when purchased. As of December 31, 2017 and 2016, cash and cash equivalents included $60.1 million and $57.6 million, respectively, of unrestricted cash held at project-level subsidiaries, which was available for project expenses but not available for corporate use. 

Restricted Cash

Restricted cash consists of cash on deposit in financial institutions that is restricted to satisfy the requirements of certain debt agreements and funds held within the Company's project companies that are restricted for current debt service payments and other purposes in accordance with the applicable debt agreements. These restrictions include: (i) cash on deposit in collateral accounts, debt service reserve accounts and maintenance reserve accounts; and (ii) cash on deposit in operating accounts but subject to distribution restrictions related to debt defaults existing as of the balance sheet date.

As discussed in Note 11. Long-term Debt, the Company was in default under certain of its non-recourse financing agreements as of the financial statement issuance date for the years ended December 31, 2017 and 2016. As a result, the


91


Company reclassified $18.8 million and $65.3 million, respectively, of long-term restricted cash to current as of December 31, 2017 and 2016, consistent with the corresponding debt classification, as the restrictions that required the cash balances to be classified as long-term restricted cash were driven by the financing agreements. As of December 31, 2017 and 2016, $21.7 million and $67.1 million, respectively, of cash and cash equivalents was also reclassified to current restricted cash as the cash balances were subject to distribution restrictions related to debt defaults that existed as of the respective balance sheet date. $33.8 million of the December 31, 2016 reclassification amount was reclassified from current restricted cash to assets held for sale as it related to the portfolios discussed in Note 4. Assets Held for Sale. There was no similar reclassification to assets held for sale for the December 31, 2017 reclassification amount as the sale of the related renewable energy facilities closed in the first half of 2017.

Accounts Receivable and Allowance for Doubtful Accounts

Accounts receivable are reported on the consolidated balance sheets, including both billed and unbilled amounts, and are adjusted for any write-offs as well as the allowance for doubtful accounts. The Company establishes an allowance for doubtful accounts to adjust its receivables to amounts considered to be ultimately collectible and charges to the allowance are recorded within general and administrative expenses in the consolidated statements of operations. The Company's allowance is based on a variety of factors, including the length of time receivables are past due, significant one-time events, the financial health of its customers and historical experience. The allowance for doubtful accounts was $1.7 million and $3.2 million as of December 31, 2017 and 2016, respectively, and charges (reductions) to the allowance recorded within general and administrative expenses for the years ended December 31, 2017, 2016 and 2015 were $(1.5) million, $0.5 million and $2.7 million, respectively. Accounts receivable are written off in the period in which the receivable is deemed uncollectible and collection efforts have been exhausted. There were no write-offs of accounts receivable for the years ended December 31, 2017, 2016 and 2015.

Renewable Energy Facilities

Renewable energy facilities consist of solar generation facilities and wind power plants that are stated at cost. Expenditures for major additions and improvements are capitalized, and minor replacements, maintenance and repairs are charged to expense as incurred. When renewable energy facilities are retired, or otherwise disposed of, the cost and accumulated depreciation is removed from the consolidated balance sheet and any resulting gain or loss is included in the results of operations for the respective period. Depreciation of renewable energy facilities is recognized using the straight-line method over the estimated useful lives of the renewable energy facilities, which range from 20 to 30 years for the Company's solar generation facilities. Effective October 1, 2016, the Company changed its estimates of the useful lives of the major components of its wind power plants to better reflect the estimated periods during which these major components will remain in service. These major components comprising the Company's wind power plants had remaining useful lives ranging from 5 to 41 years and had an overall weighted average remaining useful life of 24 years as of October 1, 2016. This prospective change in estimate increased depreciation expense and net loss by $1.9 million for the quarter and year ended December 31, 2016 and increased basic and diluted loss per share by $0.02 for the quarter and year ended December 31, 2016. These major wind components had a weighted average remaining useful life of 23 years as of December 31, 2017.

Intangibles

The Company's intangible assets and liabilities represent revenue contracts, consisting of long-term power purchase agreements (“PPAs”) and renewable energy certificates (“RECs”), lease agreements and operations and maintenance (“O&M”) contracts that were obtained through third party acquisitions. The revenue contract intangibles are comprised of favorable and unfavorable rate PPAs and REC agreements and the in-place value of market rate PPAs. The lease agreement intangibles are comprised of favorable and unfavorable rate land leases, and the O&M contract intangibles consist of unfavorable rate O&M contracts. Intangible assets and liabilities that have determinable estimated lives are amortized over those estimated lives. Amortization of favorable and unfavorable rate revenue contracts is recorded within operating revenues, net in the consolidated statements of operations. Amortization expense related to the in-place value of market rate revenue contracts is recorded within depreciation, accretion and amortization expense in the consolidated statements of operations, and amortization of favorable and unfavorable rate land leases and unfavorable rate O&M contracts is recorded within cost of operations. The straight-line method of amortization is used because it best reflects the pattern in which the economic benefits of the intangibles are consumed or otherwise used up. The amounts and useful lives assigned to intangible assets and liabilities acquired impact the amount and timing of future amortization.



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Impairment of Renewable Energy Facilities and Intangibles

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. 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 as the difference between an asset's carrying amount and fair value. Fair values are determined by a variety of valuation methods, including appraisals, sales prices of similar assets and present value techniques. During the years ended December 31, 2017 and 2016, the Company recognized a $1.4 million and $19.0 million impairment charge, respectively, related to its portfolio of residential rooftop solar assets as reflected within impairment of renewable energy facilities in the consolidated statements of operations (see Note 4. Assets Held for Sale for further discussion). There were no impairments of renewable energy facilities or intangibles recognized during the year ended December 31, 2015.

Goodwill

When the Company has goodwill, it evaluates it for impairment at least annually on December 1st. The Company performs an impairment test between scheduled annual tests if facts and circumstances indicate that it is more-likely-than-not that the fair value of a reporting unit that has goodwill is less than its carrying value.

The Company may first make a qualitative assessment of whether it is more-likely-than-not that a reporting unit’s fair value is less than its carrying value to determine whether it is necessary to perform the two-step quantitative goodwill impairment test. The qualitative impairment test includes considering various factors including macroeconomic conditions, industry and market conditions, cost factors, a sustained share price or market capitalization decrease and any reporting unit specific events. If it is determined through the qualitative assessment that a reporting unit’s fair value is more-likely-than-not greater than its carrying value, the two-step impairment test is not required. If the qualitative assessment indicates it is more-likely-than-not that a reporting unit’s fair value is not greater than its carrying value, the Company must perform the two-step impairment test. The Company may also elect to proceed directly to the two-step impairment test without considering such qualitative factors.

The first step in the two-step impairment test is the comparison of the fair value of a reporting unit with its carrying amount, including goodwill. The Company defines its reporting units to be consistent with its operating segments. In accordance with the authoritative guidance over fair value measurements, the Company defines the fair value of a reporting unit as the price that would be received to sell the unit as a whole in an orderly transaction between market participants at the measurement date. The Company primarily uses the income approach methodology of valuation, which uses the discounted cash flow method, to estimate the fair values of the Company's reporting units. The Company does not believe that a cost approach is relevant to measuring the fair values of its reporting units.

Significant management judgment is required when estimating the fair value of the Company's reporting units, including the forecasting of future operating results, the discount rates and expected future growth rates that it uses in the discounted cash flow method of valuation, and in the selection of comparable businesses that are used in the market approach. If the estimated fair value of the reporting unit exceeds the carrying value assigned to that unit, goodwill is not impaired and no further analysis is required.

If the carrying value assigned to a reporting unit exceeds its estimated fair value in the first step, then the Company is required to perform the second step of the impairment test. In this step, the Company assigns the fair value of the reporting unit calculated in step one to all of the assets and liabilities of that reporting unit as if a market participant just acquired the reporting unit in a business combination. The excess of the fair value of the reporting unit determined in the first step of the impairment test over the total amount assigned to the assets and liabilities in the second step of the impairment test represents the implied fair value of goodwill. If the carrying value of a reporting unit’s goodwill exceeds the implied fair value of goodwill, the Company would record an impairment loss equal to the difference. The Company recorded a goodwill impairment charge of $55.9 million for the year ended December 31, 2016 as reflected in the consolidated statement of operations (see Note 8. Goodwill for further discussion). As a result of this charge, the Company did not have any goodwill as of December 31, 2017 or 2016.

Capitalized Interest

Interest incurred on funds borrowed to finance construction of renewable energy facilities is capitalized until the


93


system is ready for its intended use. The amount of interest capitalized during the years ended December 31, 2016 and 2015 was $1.6 million and $22.7 million, respectively. There was no interest capitalized during the year ended December 31, 2017.

Financing Lease Obligations

Certain of the Company's assets were financed with sale-leaseback arrangements. Proceeds received from a sale-leaseback are treated using the deposit method when the sale of the renewable energy facility is not recognizable. A sale is not recognized when the leaseback arrangements include a prohibited form of continuing involvement, such as an option or obligation to repurchase the assets under the Company's master lease agreements. Under these arrangements, the Company does not recognize any profit until the sale is recognizable, which the Company expects will be at the end of the arrangement when the contract is canceled and the initial deposits received are forfeited by the financing party.
    
The Company is required to make rental payments over the course of the leaseback arrangements. These payments are allocated between principal and interest payments using an effective yield method.

Deferred Financing Costs

Financing costs incurred in connection with obtaining construction and term financing are deferred and amortized over the maturities of the respective financing arrangements using the effective interest method and are presented as a direct deduction from the carrying amount of the related debt (see Note 11. Long-term Debt), with the exception of the costs related to the Company's revolving credit facilities, which are presented as a non-current asset on the balance sheet within other assets. As of December 31, 2017 and 2016, the Company had $9.4 million and $7.8 million, respectively, of unamortized deferred financing costs related to its revolving credit facilities. The prior year amount was reclassified from deferred financing costs, net to other assets to conform to the current year presentation. Amortization of deferred financing costs is capitalized during construction and recorded as interest expense in the consolidated statements of operations following achievement of commercial operation.

Asset Retirement Obligations

Asset retirement obligations are accounted for in accordance with ASC 410-20, Asset Retirement Obligations. Retirement obligations associated with renewable energy facilities 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, and for which the timing and/or method of settlement may be conditional on a future event. Asset retirement obligations are recognized at fair value in the period in which they are incurred and the carrying amount of the related renewable energy facility is correspondingly increased. Over time, the liability is accreted to its expected future value. The corresponding renewable energy facility that is capitalized at inception is depreciated over its useful life. Historically, the Company accreted its asset retirement obligations over the term of the related PPA agreement. During the fourth quarter of 2016, the Company revised the accretion period and determined that these obligations should be accreted to expected future value over the remaining useful life of the corresponding renewable energy facility, consistent with the depreciation expense that is recorded on the asset retirement cost recognized within renewable energy facilities and with its estimate of the future timing of settlement. This change in accretion period and related estimate associated with the timing of the original undiscounted cash flows resulted in a $22.2 million reduction in the Company's asset retirement obligation and corresponding renewable energy facility carrying amount as of December 31, 2016. The Company also recorded an adjustment during the fourth quarter of 2016 to reduce previously reported accretion and depreciation expense by $4.4 million as a result of this change. $2.9 million of the accretion and depreciation expense reduction related to amounts previously reported for the year ended December 31, 2015. The quarterly accretion and depreciation expense reduction that related to each of the first three quarters of 2016 was $0.5 million. Management performed an assessment of the balance sheet and income statement impact on its previously issued filings and determined it to be immaterial.

The Company generally reviews its asset retirement obligations annually, based on its review of updated cost studies and its evaluation of cost escalation factors. The Company evaluates newly assumed costs or substantive changes in previously assumed costs to determine if the cost estimate impacts are sufficiently material to warrant application of the updated estimates to the asset retirement obligations. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost to the extent applicable. Effective December 31, 2016, the Company revised its original estimates of the costs and related amount of cash flows for certain of its asset retirement obligations which resulted in a $7.9 million reduction in the asset retirement obligation and related renewable energy facility carrying amount as of December 31, 2016. As this was a prospective change in estimate, there was no impact to accretion or


94


depreciation expense for the year ended December 31, 2016 as a result of this change. There were no similar adjustments during the years ended December 31, 2017 or 2015.

Revenue Recognition

Power Purchase Agreements

A significant majority of the Company's revenues are obtained through the sale of energy (based on megawatts, “MW”) pursuant to terms of PPAs or other contractual arrangements which have a weighted average remaining life of 14 years as of December 31, 2017. Most of the Company's PPAs are accounted for as operating leases and have no minimum lease payments. Rental income under these leases is recorded as revenue when the electricity is delivered.

Incentive Revenue

The Company generates RECs as it produces electricity. RECs are accounted for as government incentives and are not considered output of the underlying renewable energy facilities. These RECs are currently sold pursuant to agreements with unaffiliated third parties and a certain debt holder, and revenue is recognized as the underlying electricity is generated if the sale has been contracted with the customer.

The Company also receives performance-based incentives (“PBIs”) from public utilities in connection with certain locally sponsored programs. Payments are based on a fixed price per kilowatt hour (“kWh”) produced over the term of the respective program. PBI revenue is recognized as energy is generated over the term of the agreement.

Deferred Revenue

Deferred revenue primarily consists of upfront incentives or subsidies received from various state governmental jurisdictions for operating certain of the Company's renewable energy facilities or from the sale of investment tax credits to non-controlling members. The amounts deferred are recognized as revenue on a straight-line basis over the depreciable life of the renewable energy facility or upon the contingency of claw-back of the tax credits resolve as the Company fulfills its obligation to operate these renewable energy facilities. Recognition of deferred revenue was $18.2 million, $16.5 million and $9.9 million during the years ended December 31, 2017, 2016 and 2015, respectively.

Income Taxes

The Company accounts for income taxes using the liability method, 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 reports certain 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. 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. Changes to existing net deferred tax assets or valuation allowances or changes to uncertain tax benefits are recorded to income tax expense.

Non-controlling Interests and Hypothetical Liquidation at Book Value (“HLBV”)

Non-controlling interests represent the portion of net assets in consolidated entities that are not owned by the Company and are reported as a component of equity in the consolidated balance sheets. Non-controlling interests in subsidiaries that are redeemable either at the option of the holder or at fixed and determinable prices at certain dates in the future are classified as


95


redeemable non-controlling interests in subsidiaries between liabilities and stockholders' equity in the consolidated balance sheets. Redeemable non-controlling interests that are currently redeemable or redeemable after the passage of time are adjusted to their redemption value as changes occur. The Company applies the guidance in ASC 810-10 along with the SEC guidance in ASC 480-10-S99-3A in the valuation of redeemable non-controlling interests.

The Company has determined the allocation of economics between the controlling party and the third party for non-controlling interests does not correspond to ownership percentages for certain of its consolidated subsidiaries. In order to reflect the substantive profit sharing arrangements, the Company has determined that the appropriate methodology for determining the value of non-controlling interests is a balance sheet approach using the HLBV method. Under the HLBV method, the amounts reported as non-controlling interest on the consolidated balance sheets represent the amounts the third party investors could hypothetically receive at each balance sheet reporting date based on the liquidation provisions of the respective operating partnership agreements. HLBV assumes that the proceeds available for distribution are equivalent to the unadjusted, stand-alone net assets of each respective partnership, as determined under U.S. GAAP. The third party non-controlling interests in the consolidated statements of operations and statements of comprehensive loss are determined based on the difference in the carrying amounts of non-controlling interests on the consolidated balance sheets between reporting dates, adjusted for any capital transactions between the Company and third party investors that occurred during the respective period. 

Where, prior to the commencement of operating activities for a respective renewable energy facility, HLBV results in an immediate change in the carrying value of non-controlling interest on the consolidated balance sheet due to the recognition of ITCs or other adjustments as required by the U.S. Internal Revenue Code, the Company defers the recognition of the respective adjustments and recognizes the adjustments in non-controlling interest on the consolidated statement of operations on a straight-line basis over the expected life of the underlying assets giving rise to the respective difference. Similarly, where the Company has acquired a controlling interest in a partnership and there is a resulting difference between the initial fair value of non-controlling interest and the value of non-controlling interest as measured using HLBV, the Company initially records non-controlling interest at fair value and amortizes the resulting difference over the remaining life of the underlying assets.      

Contingencies

The Company is involved in conditions, situations or circumstances in the ordinary course of business with possible gain or loss contingencies that will ultimately be resolved when one or more future events occur or fail to occur. If some amount within a range of loss appears at the time to be a better estimate than any other amount within the range, that amount will be accrued. When no amount within the range is a better estimate than any other amount, the minimum amount in the range will be accrued. The Company continually evaluates uncertainties associated with loss contingencies and records a charge equal to at least the minimum estimated liability for a loss contingency when both of the following conditions are met: (i) information available prior to the issuance of the financial statements indicates that it is probable that an asset had been impaired or a liability had been incurred at the date of the financial statements; and (ii) the loss or range of loss can be reasonably estimated. Legal costs are expensed when incurred. Gain contingencies are not recorded until realized or realizable.

Derivative Financial Instruments

The Company recognizes its derivative instruments as assets or liabilities at fair value in the consolidated balance sheets. Accounting for changes in the fair value (i.e., gains or losses) of a derivative instrument depends on whether it has been designated as part of a hedging relationship and the type of hedging relationship.

The effective portion of changes in fair value of derivative instruments designated as cash flow hedges is reported as a component of other comprehensive income. Changes in the fair value of these derivatives are subsequently reclassified into earnings in the period that the hedged transaction affects earnings. The ineffective portion of changes in fair value is recorded as a component of net loss in the consolidated statements of operations.

The change in fair value of undesignated derivative instruments is reported as a component of net loss in the consolidated statements of operations.

Fair Value Measurements

The Company performs fair value measurements defined as the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. When determining the


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fair value measurements for assets and liabilities required to be recorded at their fair values, the Company considers the principal or most advantageous market in which it would transact and considers assumptions that market participants would use when pricing the assets or liabilities, such as inherent risk, transfer restrictions and risk of nonperformance.

In determining fair value measurements, the Company maximizes the use of observable inputs and minimizes the use of unobservable inputs. Assets and liabilities are categorized within a fair value hierarchy based upon the lowest level of input that is significant to the fair value measurement:

Level 1: Quoted prices in active markets for identical assets or liabilities;
Level 2: Inputs other than Level 1 that are observable, either directly or indirectly, such as quoted prices in active markets for similar assets or liabilities, quoted prices for identical or similar assets or liabilities in markets that are not active or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities; or
Level 3: Unobservable inputs that are supported by little or no market activity and that are significant to the fair values of the assets or liabilities.

The Company maintains various financial instruments recorded at cost in the consolidated balance sheets that are not required to be recorded at fair value. For cash and cash equivalents, restricted cash, accounts receivable, prepaid expenses and other current assets, accounts payable, accrued expenses and other current liabilities and due to affiliates, net, the carrying amount approximates fair value because of the short-term maturity of the instruments. See Note 14. Fair Value of Financial Instruments for disclosures related to the fair value of the Company's derivative instruments and long-term debt.

Foreign Operations

The Company's reporting currency is the U.S. dollar. Certain of the Company's subsidiaries maintain their records in local currencies other than the U.S. dollar, which are their functional currencies. When a subsidiary’s local currency is considered its functional currency, the Company translates its assets and liabilities to U.S. dollars using exchange rates in effect at the balance sheet date and its revenue and expense accounts to U.S. dollars at average exchange rates for the period. Translation adjustments are reported in accumulated other comprehensive income in stockholders’ equity. Transaction gains and losses and changes in fair value of the Company's foreign exchange derivative contracts not accounted for under hedge accounting are included in results of operations as incurred. (Gain) loss on foreign currency exchange, net was $(6.1) million, $13.0 million and $19.5 million during the years ended December 31, 2017, 2016 and 2015, respectively, as reported in the consolidated statements of operations.

Business Combinations

The Company accounts for its business combinations by recognizing in the financial statements the identifiable assets acquired, the liabilities assumed and any non-controlling interests in the acquiree at fair value at the acquisition date. The Company 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, acquisition costs related to business combinations are expensed as incurred.

When the Company acquires renewable energy facilities, the purchase price is allocated to (i) the acquired tangible assets and liabilities assumed, primarily consisting of land, plant and long-term debt, (ii) the identified intangible assets and liabilities, primarily consisting of the value of favorable and unfavorable rate PPAs and REC agreements and the in-place value of market rate PPAs, (iii) non-controlling interests, and (iv) other working capital items based in each case on their fair values.
    
The Company generally uses independent appraisers to assist with the estimates and methodologies used such as a replacement cost approach, or an income approach or excess earnings approach. Factors considered by the Company in its analysis include considering current market conditions and costs to construct similar facilities. The Company also considers information obtained about each facility as a result of its pre-acquisition due diligence in estimating the fair value of the tangible and intangible assets and liabilities acquired or assumed. In estimating the fair value the Company also establishes estimates of energy production, current in-place and market power purchase rates, tax credit arrangements and operating and maintenance costs. A change in any of the assumptions above, which are subjective, could have a significant impact on the results of operations.



97


The allocation of the purchase price directly affects the following items in the consolidated financial statements:

The amount of purchase price allocated to the various tangible and intangible assets, liabilities and non-controlling interests on the balance sheet;
The amounts allocated to the value of favorable and unfavorable rate PPAs and REC agreements are amortized to revenue over the remaining non-cancelable terms of the respective arrangement. The amounts allocated to all other tangible assets and intangibles are amortized to depreciation or amortization expense, with the exception of favorable and unfavorable rate land leases and unfavorable rate O&M contracts which are amortized to cost of operations; and
The period of time over which tangible and intangible assets and liabilities are depreciated or amortized varies, and thus, changes in the amounts allocated to these assets and liabilities will have a direct impact on the Company's results of operations.

Stock-Based Compensation

Stock-based compensation expense for all share-based payment awards to employees who provide services to the Company is based on the estimated grant-date fair value. The Company recognizes these compensation costs net of an estimated forfeiture rate for only those shares expected to vest on a straight-line basis over the requisite service period of the award, which is generally the award vesting term. For ratable awards, the Company recognizes compensation costs for all grants on a straight-line basis over the requisite service period of the entire award.

Assets Held for Sale

The Company records assets held for sale at the lower of the carrying value or fair value less costs to sell. The following criteria are used to determine if property is held for sale: (i) management has the authority and commits to a plan to sell the property; (ii) the property is available for immediate sale in its present condition; (iii) there is an active program to locate a buyer and the plan to sell the property has been initiated; (iv) the sale of the property is probable within one year; (v) the property is being actively marketed at a reasonable price relative to its current fair value; and (vi) it is unlikely that the plan to sell will be withdrawn or that significant changes to the plan will be made.

In determining the fair value of the assets less costs to sell, the Company considers factors including current sales prices for comparable assets in the region, recent market analysis studies, appraisals and any recent legitimate offers. If the estimated fair value less costs to sell of an asset is less than its current carrying value, the asset is written down to its estimated fair value less costs to sell. Due to uncertainties in the estimation process, it is reasonably possible that actual results could differ from the estimates used in the Company's historical analysis. The Company's assumptions about project sale prices require significant judgment because the current market is highly sensitive to changes in economic conditions. The Company estimates the fair values of assets held for sale based on current market conditions and assumptions made by management, which may differ from actual results and may result in additional impairments if market conditions deteriorate.

When assets are classified as held for sale, the Company does not record depreciation or amortization for the respective renewable energy facilities or intangibles.

Restructuring

The Company accounts for restructuring costs in accordance with ASC 712 and ASC 420, as applicable. In connection with the consummation of the Merger and the expected relocation of the headquarters of the Company to New York, New York, the Company announced a restructuring plan that went into effect upon the closing of the Merger. The Company recognized $3.7 million of severance and transition bonus costs related to this restructuring within general and administrative expenses in the consolidated statement of operations for the year ended December 31, 2017, of which $1.0 million was paid in the fourth quarter of 2017.

Recently Adopted Accounting Standards

In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-09, Compensation - Stock Compensation (Topic 718). This update was issued as part of the FASB's simplification initiative and affects all entities that issue share-based payment awards to their employees. The amendments in this update cover such areas as the recognition of excess tax benefits and deficiencies, the classification of those excess tax benefits on the


98


statement of cash flows, an accounting policy election for forfeitures, the amount an employer can withhold to cover income taxes and still qualify for equity classification and the classification of those taxes paid on the statement of cash flows. This update is effective for annual and interim periods beginning after December 15, 2016, with early adoption permitted if all provisions are adopted within the same period. The Company adopted ASU No. 2016-09 as of January 1, 2017, which did not result in any material adjustments to the Company's consolidated financial statements and related disclosures.

In March 2016, the FASB issued ASU No. 2016-06, Derivatives and Hedging (Topic 815), which clarifies that determining whether the economic characteristics of a put or call are clearly and closely related to its debt host requires only an assessment of the four-step decision sequence outlined in FASB ASC paragraph 815-15-25-24. Additionally, entities are not required to separately assess whether the contingency itself is clearly and closely related. This standard is effective for annual and interim periods beginning after December 15, 2016, with early adoption permitted. The amendments in this update should be applied on a modified retrospective basis. The adoption of ASU No. 2016-06 as of January 1, 2017 did not have an impact on the Company's consolidated financial statements.

In October 2016, the FASB issued ASU No. 2016-17, Consolidation (Topic 810), Interests Held through Related Parties That Are under Common Control. ASU No. 2016-17 updates ASU No. 2015-02. Under the amendments, a single decision maker is not required to consider indirect interests held through related parties that are under common control with the single decision maker to be the equivalent of direct interests in their entirety. Instead, a single decision maker is required to include those interests on a proportionate basis consistent with indirect interests held through other related parties. ASU No. 2016-17 is effective for annual reporting periods beginning after December 15, 2016, and interim periods within those annual periods, with early adoption permitted. The adoption of ASU No. 2016-17 as of January 1, 2017 did not have an impact on the Company's consolidated financial statements.

In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows (Topic 320), Restricted Cash, a Consensus of the FASB Emerging Issues Task Force. The amendments require that a statement of cash flows explain the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The Company elected to early adopt ASU No. 2016-18 during the second quarter of 2017, which requires retrospective application, and has revised its consolidated statements of cash flows for the years ended December 31, 2016 and 2015. Net cash used in investing activities for the years ended December 31, 2016 and 2015 decreased by $13.8 million and $88.0 million, respectively, as a result of the adoption of this standard. The sum of the Company's cash and cash equivalents of $565.3 million, current portion of restricted cash of $114.9 million and non-current portion of restricted cash of $2.6 million reported within the consolidated balance sheet as of December 31, 2016 equals the beginning balance of cash, cash equivalents and restricted cash of $682.8 million shown in the consolidated statement of cash flows for the year ended December 31, 2017. The sum of the Company's cash and cash equivalents of $128.1 million, current portion of restricted cash of $54.0 million and non-current portion of restricted cash of $42.7 million reported within the consolidated balance sheet as of December 31, 2017 equals the ending balance of cash, cash equivalents and restricted cash of $224.8 million shown in the consolidated statement of cash flows for the year ended December 31, 2017. The Company had $54.8 million of restricted cash classified within assets held for sale as of December 31, 2016, with no comparable amount as of December 31, 2015, and thus had to add this reclassification amount to the net change in cash, cash equivalents and restricted cash classified within assets held for sale line reported in the consolidated statement of cash flows for the year ended December 31, 2016 to reconcile the change in the beginning and end-of-period cash, cash equivalents and restricted cash. The Company's restricted cash balances during 2016 and 2015 also included amounts related to its renewable energy facilities located in the United Kingdom (the “U.K.”) and Canada, which resulted in a $7.9 million and $2.5 million change in the effect of exchange rate changes on cash, cash equivalents and restricted cash line reported in the consolidated statements of cash flows for the years ended December 31, 2016 and 2015, respectively.

In December 2016, the FASB issued ASU No. 2016-19, Technical Corrections and Improvements. The amendments cover a wide range of topics in the Accounting Standards Codification, covering differences between original guidance and the Accounting Standards Codification, guidance clarification and reference corrections, simplification and minor improvements. The adoption of ASU No. 2016-19 is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. The Company evaluated this standard and determined that it did not have an impact on its consolidated financial statements.


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Recently Issued Accounting Standards Not Yet Adopted

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU No. 2014-09 will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. In March 2016, the FASB issued ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606), Principal versus Agent Considerations (Reporting Revenue Gross versus Net), which clarifies how to apply the implementation guidance on principal versus agent considerations related to the sale of goods or services to a customer as updated by ASU No. 2014-09. ASU No. 2014-09 and ASU No. 2016-08 will become effective for the Company on January 1, 2018. ASU No. 2014-09 and ASU No. 2016-08 permit the use of either the retrospective or modified retrospective method.

The Company has analyzed the impact of Topic 606 on its revenue contracts which primarily include bundled energy and incentive sales through PPAs, individual REC sales, and upfront sales of federal & state incentive benefits recorded as deferred revenue and accreted into revenue. The Company has determined to apply a modified retrospective approach with a cumulative adjustment to accumulated deficit as of January 1, 2018 for changes to revenue recognition resulting from Topic 606 adoption.

The Company accounts for the majority of its PPAs as operating leases under ASC 840, Leases and recognizes rental income as revenue when the electricity is delivered. The Company has elected not to early adopt ASC 842, Leases in fiscal 2018 and therefore these PPAs are currently being evaluated in anticipation of the new lease standard adoption in fiscal 2019. For the bundled PPAs under the scope of Topic 606 in fiscal 2018, we concluded there will be no material change to revenue recognition patterns from current accounting practice.

The Company has evaluated the impact of Topic 606 as it relates to the individual sale of RECs. In certain jurisdictions, there may be a lag between physical generation of the underlying energy and the transfer of RECs to the customer due to administrative processes imposed by state regulations. Under the Company’s current accounting policy, the revenue is recognized as the underlying electricity is generated if the sale has been contracted with the customer. Based on the framework in Topic 606, for a portion of the existing individual REC sale arrangements where the transfer of control to the customer is determined to occur upon the transfer of the RECs, the Company will initiate revenue recognition commensurate with the transfer of RECs to the customer as compared to the generation of the underlying energy under the current accounting policy. The adoption of Topic 606 is expected to result in an increase in accumulated deficit on January 1, 2018 of approximately $25 million. The Company expects the impact on its fiscal 2018 results of operations will be minimal.

The Company has evaluated the impact of Topic 606 as it relates to the upfront sale of ITCs through its lease pass-through fund arrangements. The Company has concluded that revenue related to the sale of ITCs through its lease pass-through arrangements will be recognized at the point in time when the related solar energy systems are placed in service. Currently, the Company recognizes this revenue evenly over the five-year ITC recapture period. The adoption of Topic 606 is anticipated to be material to fiscal 2018. The adjustment on January 1, 2018 from the adoption is expected to decrease accumulated deficit by approximately $41 million. The Company expects the impact on its fiscal 2018 results of operations to result in a decrease in non-cash deferred revenue recognition of approximately $16 million.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), which primarily changes the lessee's accounting for operating leases by requiring recognition of lease right-of-use assets and lease liabilities. The Company expects to adopt the standard on January 1, 2019. The issued guidance requires a modified retrospective transition approach, which requires entities to recognize and measure leases at the beginning of the earliest period presented. In January 2018, the FASB proposed amending the standard to give entities another option for transition. The proposed transition method would allow entities to initially apply the requirements of the standard in the period of adoption (January 1, 2019). The Company will assess this transition option if the FASB issues the revised standard. The Company expects to elect certain of the practical expedients permitted in the issued standard, including the expedient that permits the Company to retain its existing lease assessment and classification. In January 2018, the FASB issued additional guidance which provides another optional transition practical expedient that allows entities to not evaluate existing and expired land easements under the new guidance at adoption if they were not previously accounted for as leases. The Company is currently working through an adoption plan which includes the evaluation of lease contracts compared to the new standard. While the Company is currently evaluating the impact the new guidance will have on its financial position and results of operations, the Company expects to recognize lease liabilities and


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right of use assets. The extent of the increase to assets and liabilities associated with these amounts remains to be determined pending the Company’s review of its existing lease contracts which may contain embedded leases.

In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230), Classification of Certain Cash Receipts and Cash Payments. The amendments of ASU No. 2016-15 were issued to address eight specific cash flow issues for which stakeholders have indicated to the FASB that a diversity in practice existed in how entities were presenting and classifying these items in the statement of cash flows. The issues addressed by ASU No. 2016-15 include but are not limited to the classification of debt prepayment and debt extinguishment costs, payments made for contingent consideration for a business combination, proceeds from the settlement of insurance proceeds, distributions received from equity method investees and separately identifiable cash flows and the application of the predominance principle. The amendments of ASU No. 2016-15 are effective for public entities for fiscal years beginning after December 15, 2017 and interim periods in those fiscal years. The adoption of ASU No. 2016-15 is required to be applied retrospectively. The Company does not expect this standard to have a material impact on its consolidated statements of cash flows.

In October 2016, the FASB issued ASU No. 2016-16, Income Taxes (Topic 740), Intra-Entity Transfers of Assets Other Than Inventory. The amendments of ASU No. 2016-16 were issued to improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. Current GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party which has resulted in diversity in practice and increased complexity within financial reporting. The amendments of ASU No. 2016-16 would require an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs and do not require new disclosure requirements. The amendments of ASU No. 2016-16 are effective for annual reporting periods beginning after December 15, 2017, and interim periods within those annual periods. The adoption of ASU No. 2016-16 should be applied on a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company does not expect this standard to have an impact on its consolidated financial statements.

In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805), Clarifying the Definition of a Business. The amendment seeks to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The definition of a business affects many areas of accounting including acquisitions, disposals, goodwill and consolidation. The adoption of ASU No. 2017-01 is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The amendments should be applied prospectively on or after the effective dates. Accordingly, the adoption will not have an effect on the Company's historical financial statements.

In January 2017, the FASB issued ASU No. 2017-04, Intangibles - Goodwill and Other (Topic 350), Simplifying the Test for Goodwill Impairment. The amendment simplifies the accounting for goodwill impairment by removing Step 2 of the current test, which requires calculation of a hypothetical purchase price allocation. Under the revised guidance, goodwill impairment will be measured as the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill (currently Step 1 of the two step impairment test). Entities will continue to have the option to perform a qualitative assessment to determine if a quantitative impairment test is necessary. The standard is effective January 1, 2020, with early adoption permitted, and must be adopted on a prospective basis. This updated guidance is not currently expected to impact the Company's financial reporting as the Company does not have any goodwill. The Company will evaluate the impact of this standard in the future should it consummate any acquisition that results in the recognition of goodwill.

In February 2017, the FASB issued ASU No. 2017-05, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets. This ASU is meant to clarify the scope of ASC Subtopic 610-20, Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets and to add guidance for partial sales of nonfinancial assets. ASU No. 2017-05 is to be applied using a full retrospective method or a modified retrospective method as outlined in the guidance and is effective at the same time as ASU No. 2014-09. Further, the Company is required to adopt ASU No. 2017-05 at the same time that it adopts the guidance in ASU No. 2014-09. The Company is currently evaluating the effect of this standard on its consolidated financial statements.

In May 2017, the FASB issued ASU No. 2017-09, Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting. The amendment clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as a modification. The new guidance is expected to reduce diversity in practice and result in fewer


101


changes to the terms of an award being accounted for as a modification. Changes to the terms or conditions of a share-based payment award that do not impact the fair value of the award, vesting conditions and the classification as an equity or liability instrument will not need to be assessed under modification accounting. The guidance is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2017. The amendments in this update should be applied prospectively to an award modified on or after the adoption date. Accordingly, the adoption will not have an effect on the Company's historical financial statements.

In August 2017, the FASB issued ASU No. 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities. This ASU amends the hedge accounting model to enable entities to better portray the economics of their risk management activities in the financial statements and simplifies the application of hedge accounting in certain situations. ASU No. 2017-12 is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2018, with early adoption permitted. The Company is currently evaluating the effect of this standard on its consolidated financial statements.

In February 2018, the FASB issued ASU No. 2018-02, Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income, to help entities address certain stranded income tax effects in accumulated other comprehensive income resulting from the U.S. government's enactment of the Tax Cuts and Jobs Act (the “Tax Act”) on December 22, 2017. The amendment provides entities with an option to reclassify stranded tax effects within accumulated other comprehensive income to retained earnings in each period in which the effect of the change in the U.S. federal corporate income tax rate in the Tax Act (or portion thereof) is recorded. The amendment also includes disclosure requirements regarding the issuer’s accounting policy for releasing income tax effects from accumulated other comprehensive income. The optional guidance is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2018. Early adoption is permitted, and entities should apply the provisions of the amendment either in the period of adoption or retrospectively to each period (or periods) in which the effect of the change in the U.S. federal corporate income tax rate in the Tax Act is recognized. The Company is currently evaluating whether it will adopt the new guidance along with any related impacts it may have on the Company’s consolidated financial statements.

3. TRANSACTIONS BETWEEN ENTITIES UNDER COMMON CONTROL

Acquisitions of Renewable Energy Facilities from SunEdison

The following tables summarize the renewable energy facilities acquired by the Company from SunEdison through a series of transactions during the years ended December 31, 2016 and 2015. There were no renewable energy facilities acquired from SunEdison during the year ended December 31, 2017. As TerraForm Power was a controlled affiliate of SunEdison during 2016 and 2015, the assets and liabilities transferred to the Company from SunEdison related to interests under common control with SunEdison, and accordingly, were recorded at historical cost. The difference between the cash purchase price and historical cost of the net assets acquired was recorded as a contribution or distribution from SunEdison, as applicable, upon final funding of the acquisition.
 
 
 
 
 
 
Year Ended December 31, 2016
 
As of December 31, 2016
Facility Category
 
Type
 
Location
 
Nameplate Capacity (MW)
 
Number of Sites
 
Cash Paid1
 
Cash Due to SunEdison2
 
Debt Assumed
 
Debt Transferred3
Distributed Generation
 
Solar
 
U.S.
 
1.2

 
3

 
$
2,750

 
$

 
$

 
$

Utility
 
Solar
 
U.S.
 
18.0

 
1

 
36,231

 

 

 

Total
 
 
 
 
 
19.2

 
4

 
$
38,981

 
$

 
$

 
$

————
(1)
Represents the total amount paid to SunEdison. Excludes aggregated tax equity partner payments of $1.6 million to SunEdison.
(2)
All amounts were paid to SunEdison for these renewable energy facilities as of December 31, 2016.
(3)
$16.7 million of construction debt existed for one of the renewable energy facilities as of the acquisition date. This debt was fully repaid by SunEdison during the third quarter of 2016 using cash proceeds paid by the Company to SunEdison for the acquisition of the facility.


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Year Ended December 31, 2015
 
As of December 31, 2015
Facility Category
 
Type
 
Location
 
Nameplate Capacity (MW)
 
Number of Sites
 
Cash Paid1
 
Cash Due to SunEdison2
 
Debt Assumed3
 
Debt Transferred4
Distributed Generation
 
Solar
 
U.S.
 
91.5

 
74

 
$
155,573

 
$
2,600

 
$

 
$

Residential
 
Solar
 
U.S.
 
12.9

 
1,806

 
25,053

 

 

 

Utility
 
Solar
 
U.S.
 
54.8

 
9

 
69,868

 
14,341

 

 
14,475

Utility
 
Solar
 
U.K.
 
214.3

 
14

 
150,595

 

 
205,587

 

Utility
 
Wind
 
U.S.
 
200.0

 
1

 
127,000

 

 

 

Total
 
 
 
 
 
573.5

 
1,904

 
$
528,089

 
$
16,941

 
$
205,587

 
$
14,475

————
(1)
Represents the amount paid to SunEdison as of December 31, 2015. Excludes aggregated tax equity partner payments of $363.6 million to SunEdison, of which $0.7 million was refunded to the respective tax equity partner for one of the acquired projects in 2016.
(2)
Represents commitments by the Company to SunEdison for the amount required for SunEdison to complete the construction of renewable energy facilities acquired from SunEdison, which was paid to SunEdison during the first quarter of 2016. Excludes tax equity partner payments of $9.2 million due to SunEdison, which were paid during the first quarter of 2016.
(3)
Represents debt that was assumed by the Company as of the acquisition date of these facilities which was subsequently refinanced on November 6, 2015 (see Note 11. Long-term Debt).
(4)
Represents debt that was recorded on the Company's balance sheet as of such date. This debt was repaid by SunEdison during the first quarter of 2016 using cash proceeds paid by the Company and the tax equity partner to SunEdison for the acquisition of these facilities.

The difference between the cash paid and historical cost of the net assets acquired from SunEdison for projects that achieved final funding during the years ended December 31, 2016 and 2015 was $19.5 million and $41.8 million, respectively, and was recorded as a net contribution from SunEdison, which is reflected within Net SunEdison investment on the consolidated statements of stockholders' equity.

The operating revenues of the facilities acquired from SunEdison in 2016 and 2015 reflected in the consolidated statements of operations for the years ended December 31, 2016 and 2015, respectively, are $2.3 million and $37.6 million. The net income (loss) of the facilities acquired from SunEdison in 2016 and 2015 reflected in the consolidated statements of operations for the years ended December 31, 2016 and 2015, respectively, are $0.7 million and $(3.9) million.

4. ASSETS HELD FOR SALE

U.K. Portfolio Sale    

The Company commenced a sale of substantially all of its portfolio of solar power plants located in the U.K. through a broad based sales process pursuant to a plan approved by management during 2016 (24 operating projects for sale representing an aggregate 365.0 MW, the “U.K. Portfolio”), and it was determined that this portfolio met the criteria to be classified as held for sale during the first quarter of 2016. As a result, the Company classified the assets and liabilities of this portfolio as held for sale as of December 31, 2016 (refer to the table below) and measured each at the lower of carrying value or fair value less costs to sell. The Company's analysis indicated that the fair value less costs to sell exceeded the carrying value of the assets for each period the portfolio was classified as held for sale.

On May 11, 2017, the Company announced that TerraForm Power Operating, LLC (“Terra Operating LLC”) completed its sale of the U.K. Portfolio to Vortex Solar UK Limited, a renewable energy platform managed by the private equity arm of EFG Hermes, an investment bank. Terra Operating LLC received approximately $214.1 million of proceeds from the sale, which was net of transaction expenses of $3.9 million and distributions taken from the U.K. Portfolio after announcement and before closing of the sale. The Company also disposed of $14.8 million of cash and cash equivalents and $21.8 million of restricted cash as a result of the sale. The proceeds were used for the reduction of the Company's indebtedness (a $30.0 million prepayment for the Midco Portfolio Term Loan (as defined in Note 11. Long-term Debt) and the remainder was applied towards revolving loans outstanding under the Revolver (also defined in Note 11. Long-term Debt)). The sale also resulted in a reduction in the Company's non-recourse project debt by approximately 301 million British Pounds (“GBP”) at the U.K. Portfolio level. The Company recognized a gain on the sale of $37.1 million which is reflected within gain on sale of


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renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2017. The Company has retained an 11.1 MW solar asset in the U.K., which is not held for sale.

Residential Portfolio Sale

The Company also began exploring a sale of substantially all of its portfolio of residential rooftop solar assets located in the United States (11.4 MW of assets as described below) through a strategic sales process in 2016, and it was determined that these assets met the criteria to be classified as held for sale during the fourth quarter of 2016. As a result, the Company classified the related assets and liabilities as held for sale as of December 31, 2016 (refer to the table below) and measured each at the lower of carrying value or fair value less costs to sell. The Company's analysis indicated that the carrying value of the assets exceeded the fair value less costs to sell, and thus an impairment charge of $15.7 million was recognized within impairment of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2016. The Company also recorded a $3.3 million charge within impairment of renewable energy facilities for the year ended December 31, 2016 due to the decision to abandon certain residential construction in progress assets that were not completed by SunEdison as a result of the SunEdison Bankruptcy.

In the first half of 2017, the Company closed on the sale of 100% of the membership interests of Enfinity Colorado DHA 1, LLC, a Colorado limited liability company that owns and operates 2.5 MW of solar installations situated on the roof of public housing units located in Colorado and owned by the Denver Housing Authority, and 100% of the membership interests of TerraForm Resi Solar Manager, LLC, a subsidiary of the Company that owns and operates 8.9 MW of rooftop solar installations, to Greenbacker Residential Solar II, LLC. The Company received proceeds of $7.1 million during 2017 as a result of the sale of these companies and also disposed of $0.6 million of cash and cash equivalents and $0.8 million of restricted cash. There was no additional loss recognized during 2017 as a result of these sales.

The Company sold its remaining 0.3 MW of residential assets (that were not classified as held for sale as of December 31, 2016) during the third quarter of 2017. These assets did not meet the criteria for held for sale classification in the second quarter of 2017 but the Company determined that certain impairment indicators were present and as a result recognized an impairment charge of $1.4 million during the second quarter which is reflected within impairment of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2017. There was no additional loss recognized during the second half of 2017 as a result of the sale.



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The following table summarizes the major classes of assets and liabilities which are classified as held for sale on the Company's consolidated balance sheet as of December 31, 2016. As discussed above, the Company closed on the sale of these renewable energy facilities in the first half of 2017.
 
 
As of December 31, 2016
(In thousands)
 
U.K. Portfolio
 
Residential Portfolio
 
Total
Assets held for sale:
 
 
 
 
 
 
Restricted cash
 
$
53,604

 
$
1,202

 
$
54,806

Accounts receivable, net
 
4,952

 
300

 
5,252

Prepaid expenses and other current assets
 
1,295

 
170

 
1,465

Total current assets held for sale
 
59,851

 
1,672

 
61,523

 
 
 
 
 
 
 
Renewable energy facilities, net
 
529,154

 
19,534

 
548,688

Intangible assets, net
 
1,480

 

 
1,480

Other assets
 
2,103

 

 
2,103

Total non-current assets held for sale
 
532,737

 
19,534

 
552,271

 
 
 
 
 
 
 
Total assets held for sale
 
$
592,588

 
$
21,206

 
$
613,794

 
 
 
 
 
 
 
Liabilities related to assets held for sale:
 
 
 
 
 
 
Current portion of long-term debt
 
$
14,510

 
$
175

 
$
14,685

Accounts payable, accrued expenses and other current liabilities
 
5,980

 
245

 
6,225

Deferred revenue
 

 
10

 
10

Due to affiliates, net
 
692

 
186

 
878

Total current liabilities related to assets held for sale
 
21,182

 
616

 
21,798

 
 
 
 
 
 
 
Long-term debt, less current portion
 
349,687

 
4,190

 
353,877

Deferred revenue, less current portion
 

 
246

 
246

Asset retirement obligations
 
39,563

 
287

 
39,850

Other long-term liabilities
 
16,786

 

 
16,786

Total non-current liabilities related to assets held for sale
 
406,036

 
4,723

 
410,759

 
 
 
 
 
 
 
Total liabilities related to assets held for sale
 
$
427,218

 
$
5,339

 
$
432,557


5. ACQUISITIONS

2015 Acquisitions

Acquisition of First Wind

On January 29, 2015, the Company, through Terra LLC, acquired from First Wind Holdings, LLC (together with its subsidiaries, “First Wind”) operating renewable energy facilities that have a combined nameplate capacity of 521.1 MW, including 500.0 MW of wind power plants and 21.1 MW of solar generation facilities (the “First Wind Acquisition”). The operating renewable energy facilities the Company acquired are located in Maine, New York, Hawaii, Vermont and Massachusetts and are contracted under PPAs including energy hedge contracts. Certain of the renewable energy facilities also receive revenue from RECs. The cash purchase price for this acquisition was $811.6 million, net of cash acquired.

During the year ended December 31, 2015, the Company acquired an operating wind facility located in Texas and seven solar generation facilities located in Utah from SunEdison with a combined nameplate capacity of 222.6 MW. These facilities were initially acquired by SunEdison from First Wind on January 29, 2015. The purchase price paid by SunEdison to the third party for these facilities was $168.4 million, net of cash acquired. The acquisitions were treated as transactions


105


between entities under common control and as a result the acquisition accounting as of January 29, 2015 by SunEdison has been reflected in the Company's consolidated financial statements.
Acquisition of Northern Lights Solar Generation Facilities
 
On June 30, 2015, the Company acquired two utility-scale, ground mounted solar generation facilities (“Northern Lights”) from Invenergy Solar LLC. The facilities are located in Ontario, Canada and have a combined nameplate capacity of 25.4 MW. The facilities are contracted under long-term PPAs with an investment grade utility that had a credit rating of Aa2 as of the acquisition date. The purchase price for this acquisition was 125.4 million Canadian Dollars (“CAD”) (equivalent of $101.1 million on the acquisition date), net of cash acquired, including the repayment of project-level debt and breakage fees for the termination of interest rate swaps.

Acquisition of Invenergy Wind Power Plants

On December 15, 2015, the Company acquired operating wind power plants with a combined nameplate capacity of 831.5 MW (net) from Invenergy Wind Global LLC (together with its subsidiaries, “Invenergy Wind”) for $1.3 billion in cash and the assumption of $531.2 million of non-recourse indebtedness. The wind power plants that the Company acquired from Invenergy Wind have contracted PPAs and had an average counterparty credit rating of AA as of the acquisition date. Invenergy Wind retained a 9.9% non-controlling interest in the wind power plants located in the U.S. that the Company acquired and is providing certain O&M services for such assets.

Acquisition of Integrys Solar Generation Facilities

During the year ended December 31, 2015, the Company acquired 56 solar generation facilities with a combined nameplate capacity of 32.0 MW (net) from Integrys Group, Inc. (“Integrys”) for a purchase price of $70.7 million, net of cash acquired, and $15.9 million of project-level debt assumed. The facilities are located in Arizona, California, Connecticut, Massachusetts, New Jersey and Pennsylvania. The facilities are contracted under long-term PPAs with commercial and municipal customers.

Acquisition of Other Solar Generation Facilities

During the year ended December 31, 2015, the Company acquired two solar generation facilities from SunEdison with a combined nameplate capacity of 38.8 MW. These facilities were initially acquired by SunEdison through other unaffiliated third parties during the year ended December 31, 2015. The purchase price paid by SunEdison to the third parties for these acquisitions was $18.9 million, net of cash acquired. The acquisitions were treated as transactions between entities under common control and as a result the acquisition accounting by SunEdison has been reflected in the Company's consolidated financial statements.
During the year ended December 31, 2015, the Company acquired 10 solar generation facilities with a combined nameplate capacity of 3.8 MW for a purchase price of $19.9 million, net of cash acquired. The facilities are located in Ontario, Canada.



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Acquisition Accounting for the 2015 Acquisitions

The acquisition accounting for the First Wind, Northern Lights, Integrys and other solar generation facilities acquisitions was completed as of the fourth quarter of 2015, at which point the provisional fair values became final. The final acquisition-date fair values of assets, liabilities and non-controlling interests for these business combinations, were as follows:
(In thousands)
First Wind
 
Other First Wind1
 
Northern Lights
 
Integrys
 
Other
Renewable energy facilities in service
$
795,462

 
$

 
$
62,018

 
$
69,935

 
$
7,931

Construction in progress

 
264,858

 

 

 
28,878

Accounts receivable
30,031

 

 
1,361

 
2,610

 

Intangible assets
123,600

 

 
39,000

 
28,966

 
12,454

Restricted cash
7,240

 
60

 

 
827

 

Derivative assets
44,755

 

 

 

 

Other assets
5,873

 

 
11

 
234

 
200

Total assets acquired
1,006,961

 
264,918

 
102,390

 
102,572

 
49,463

Accounts payable, accrued expenses and other current liabilities
9,854

 
442

 
440

 
409

 
1,854

Long-term debt, including current portion
47,400

 
72,881

 

 
15,882

 

Asset retirement obligations
19,890

 

 
818

 
5,730

 
509

Other long-term liabilities
18,562

 
23,237

 

 
5,786

 

Total liabilities assumed
95,706

 
96,560

 
1,258

 
27,807

 
2,363

Redeemable non-controlling interest
3,076

 

 

 

 
8,298

Non-controlling interest
96,624

 

 

 
4,045

 

Purchase price, net of cash acquired
$
811,555

 
$
168,358

 
$
101,132

 
$
70,720

 
$
38,802

————
(1)
Represents renewable energy facilities with a combined nameplate capacity of 222.6 MW acquired from SunEdison during the year ended December 31, 2015. These facilities were acquired by SunEdison from First Wind on January 29, 2015.



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The acquisition accounting for the Invenergy Wind acquisition was initially completed as of the second quarter of 2016, at which point the provisional fair values became final. However, during the fourth quarter of 2016, management identified immaterial errors in the final opening balance sheet. These opening balance sheet errors, including the income statement impact, were corrected in the fourth quarter of 2016. The income statement impact resulted in an increase to depreciation expense and a net decrease to amortization expense. Management performed an assessment of the balance sheet and income statement impact on its previously issued second and third quarter filings and determined it to be immaterial. The final acquisition-date fair values of assets, liabilities and non-controlling interests pertaining to the Invenergy Wind acquisition as of December 31, 2016, the balance sheet error corrections in the fourth quarter of 2016 and the initial opening balance sheet as of December 31, 2015, were as follows:
 
Invenergy Wind Acquisition-date Fair Values
(In thousands)
As of December 31, 2015
 
Acquisition Accounting Adjustments
 
As of June 30, 2016
 
Q4 2016 Corrections
 
As of December 31, 2016
Renewable energy facilities
$
1,486,746

 
$
(8,858
)
 
$
1,477,888

 
$
45,903

 
$
1,523,791

Accounts receivable
25,811

 

 
25,811

 

 
25,811

Intangible assets
748,300

 

 
748,300

 
(37,000
)
 
711,300

Restricted cash
31,247

 

 
31,247

 

 
31,247

Derivative assets
32,311

 

 
32,311

 

 
32,311

Other assets
12,070

 
8,078

 
20,148

 

 
20,148

Total assets acquired
2,336,485

 
(780
)
 
2,335,705

 
8,903

 
2,344,608

Accounts payable, accrued expenses and other current liabilities
23,195

 

 
23,195

 
3,041

 
26,236

Long-term debt, including current portion
531,221

 

 
531,221

 

 
531,221

Deferred income taxes
242

 

 
242

 

 
242

Asset retirement obligations
47,346

 

 
47,346

 

 
47,346

Other long-term liabilities
6,004

 

 
6,004

 
5,000

 
11,004

Total liabilities assumed
608,008

 

 
608,008

 
8,041

 
616,049

Redeemable non-controlling interest
141,415

 
(780
)
 
140,635

 
(7,138
)
 
133,497

Non-controlling interest
308,000

 

 
308,000

 
8,000

 
316,000

Purchase price, net of cash acquired
$
1,279,062

 
$

 
$
1,279,062

 
$

 
$
1,279,062


The acquired renewable energy facilities' non-financial assets and other long-term liabilities primarily represent estimates of the fair value of acquired PPA and REC contracts based on significant inputs that are not observable in the market and thus represent a Level 3 measurement (as defined in Note 14. Fair Value of Financial Instruments). The estimated fair values were determined based on an income approach. Refer below for additional disclosures related to the acquired intangibles.

The operating revenues and net loss of the facilities acquired in 2015 reflected in the consolidated statement of operations for the year ended December 31, 2015 were $161.1 million and $8.8 million, respectively.

Valuation of Non-controlling Interest

First Wind

The majority of the fair value of the non-controlling interest was determined using a market approach using a quoted price for the instrument. Upon the acquisition of the First Wind assets, the Company purchased a portion of the equity interest from the non-controlling interest holders of one of the joint venture investment funds. The quoted price for the purchase of a portion of the non-controlling interest is the best indicator of fair value and was supported by a discounted cash flow technique. The Company estimated the fair value of the remainder of the non-controlling interest balances using a discounted cash flow approach.



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Invenergy Wind

The fair value of the non-controlling interest for Invenergy Wind was determined using a discounted cash flow approach. The non-controlling interest represents the fair value of 9.9% sponsor equity held by Invenergy Wind. Sun Edison LLC, a wholly owned subsidiary of SunEdison, acting as intermediary, entered into certain option arrangements with Invenergy Wind for its remaining 9.9% interest in the acquired companies (the ‘‘Invenergy Wind Interest’’). Simultaneously, Terra LLC entered into a back to back option agreement with Sun Edison LLC on substantially identical terms (collectively, the “Option Agreements”). The Option Agreements effectively permitted (i) Terra LLC to exercise a call option to purchase the Invenergy Wind Interest over a 180-day period beginning on September 30, 2019, and (ii) Invenergy Wind to exercise a put option with respect to the Invenergy Wind Interest over a 180-day period beginning on September 30, 2018. The exercise prices of the put and call options described above were to be based on the determination of the fair market value of the Invenergy Wind Interest at the time the relevant option was exercised, subject to certain minimum and maximum thresholds set forth in the Option Agreements. The minimum put option price per the Option Agreements was $137.8 million in aggregate. As the put options represented redemption rights outside the control of the Company, this non-controlling interest was classified as a redeemable non-controlling interest as of the acquisition date and as of December 31, 2016. The Company was accreting this redeemable non-controlling interest, using the straight-line method, from the acquisition date fair value to the redemption value, which was to extend through the period ended September 30, 2018. Accretion adjustments to the carrying value of this redeemable non-controlling interest were recorded against additional paid-in capital. As part of the Settlement Agreement with SunEdison, the Option Agreement between Terra LLC and Sun Edison LLC was rejected upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017. As a result, the Company is no longer obligated to perform on its Option Agreement, and as of October 16, 2017, the Invenergy Wind non-controlling interest was no longer considered redeemable and accretion ceased as of such date. See Note 18. Non-controlling Interests for further discussion.



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2015 Acquisitions - Intangibles at Acquisition Date
    
The following table summarizes the final fair value and weighted average amortization period of acquired intangible assets and liabilities as of the acquisition date for transactions closed during 2015. The acquisition accounting was finalized during 2015 for all 2015 acquisitions, with the exception of Invenergy Wind, which was finalized in 2016. The final intangibles fair value reflects the following changes from the initial opening balance sheet for Invenergy; a decrease of $2.7 million to favorable rate revenue contracts, a decrease of $34.3 million to the in-place value of market rate revenue contracts and an increase of $5.0 million to unfavorable rate O&M contracts.
 
Fair Value
(In thousands)
Invenergy
Wind
 
First
Wind
 
Northern
Lights
 
Integrys
 
Other
Intangible assets
 
 
 
 
 
 
 
 
 
Favorable rate revenue contracts
$
547,300

 
$
3,900

 
$
39,000

 
$
21,168

 
$
12,454

In-place value of market rate revenue contracts
164,000

 
103,900

 

 
7,798

 

Favorable rate land leases

 
15,800

 

 

 

Intangible liabilities


 


 


 


 


Unfavorable rate revenue contracts

 
17,200

 

 
5,786

 

Unfavorable rate O&M contracts
5,000

 

 

 

 

Unfavorable rate land lease

 
1,000

 

 

 

 
 
 
 
 
 
 
 
 
 
 
Weighted Average Amortization Period1
(In years)
Invenergy
Wind
 
First
Wind
 
Northern
Lights
 
Integrys
 
Other
Intangible assets
 
 
 
 
 
 
 
 
 
Favorable rate revenue contracts
17
 
3
 
18
 
12
 
20
In-place value of market rate revenue contracts
22
 
18
 
 
22
 
Favorable rate land leases
 
20
 
 
 
Intangible liabilities

 

 

 

 

Unfavorable rate revenue contracts
 
6
 
 
19
 
Unfavorable rate O&M contracts
4
 
 
 
 
Unfavorable rate land lease
 
18
 
 
 
————
(1)
For purposes of this disclosure, the weighted average amortization period is determined based on a weighting of the individual intangible fair values against the total fair value for each major intangible asset and liability class.

Unaudited Pro Forma Supplementary Data

The unaudited pro forma supplementary data presented in the table below gives effect to the significant 2015 acquisitions, Invenergy Wind, First Wind and Northern Lights, as if those transactions had each occurred on January 1, 2014. The unaudited pro forma supplementary data is provided for informational purposes only and should not be construed to be indicative of the Company’s results of operations had the acquisitions been consummated on the date assumed or of the Company’s results of operations for any future date.
(In thousands, unaudited)
Year Ended December 31, 2015
Total operating revenues, net
$
605,441

Net loss
(128,588
)

Acquisition costs incurred by the Company related to third party acquisitions were $2.7 million and $55.8 million for the years ended December 31, 2016 and 2015, respectively. There were no acquisition costs incurred for the year ended December 31, 2017. These costs are reflected as acquisition and related costs and acquisition and related costs - affiliate in the consolidated statements of operations and are excluded from the unaudited pro forma net loss amount disclosed above.


110



6. RENEWABLE ENERGY FACILITIES

Renewable energy facilities, net consists of the following: 
 
 
As of December 31,
(In thousands)
 
2017
 
2016
Renewable energy facilities in service, at cost
 
$
5,378,462

 
$
5,354,883

Less accumulated depreciation - renewable energy facilities
 
(578,474
)
 
(364,756
)
Renewable energy facilities in service, net
 
4,799,988

 
4,990,127

Construction in progress - renewable energy facilities
 
1,937

 
3,124

Total renewable energy facilities, net
 
$
4,801,925

 
$
4,993,251


Depreciation expense related to renewable energy facilities was $212.6 million, $209.2 million and $135.7 million for the years ended December 31, 2017, 2016 and 2015, respectively.

As of December 31, 2017, construction in progress primarily represented initial costs incurred for the construction of a new battery energy storage system for one of the Company's wind power plants, for which construction began in the fourth quarter of 2017. As of December 31, 2016, construction in progress represented costs incurred to complete the construction of the facilities in the Company's portfolio that were acquired from SunEdison and is stated at SunEdison's historical cost. Construction in progress amounts include capitalized interest costs and amortization of deferred financing costs incurred during the asset's construction period when funds are borrowed to finance construction, which totaled $1.6 million and $22.7 million during the years ended December 31, 2016 and 2015, respectively. There was no capitalization of interest costs or deferred financing cost amortization for the year ended December 31, 2017.

As of December 31, 2016, the Company reclassified $548.7 million from renewable energy facilities, net to non-current assets held for sale in the consolidated balance sheet. There was no similar reclassification as of December 31, 2017 as the sale of these renewable energy facilities closed in the first half of 2017 (see Note 4. Assets held for Sale).

7. ASSET RETIREMENT OBLIGATIONS

Activity in asset retirement obligations for the years ended December 31, 2017, 2016 and 2015 was as follows:
 
 
Year Ended December 31,
(In thousands)
 
2017
 
2016
 
2015
Balance as of the beginning of the year
 
$
148,575

 
$
215,146

 
$
78,175

Additional obligations from renewable energy facilities achieving commercial
operation
 

 
2,132

 
52,181

Revisions in estimates for current obligations1
 

 
(7,920
)
 

Adjustment related to change in accretion period2
 

 
(22,204
)
 

Assumed through acquisition
 

 
136

 
74,293

Acquisition accounting adjustments related to prior year acquisitions
 

 

 
5,640

Accretion expense
 
8,578

 
8,992

 
7,209

Reclassification to non-current liabilities related to assets held for sale
 

 
(39,850
)
 

Other
 
(3,238
)
 

 

Currency translation adjustment
 
600

 
(7,857
)
 
(2,352
)
Balance as of the end of the year
 
$
154,515

 
$
148,575

 
$
215,146

————
(1)
As discussed in Note 2. Summary of Significant Accounting Policies, effective December 31, 2016, the Company revised its original estimates of the costs and related amount of cash flows for certain of its asset retirement obligations.
(2)
As discussed in Note 2. Summary of Significant Accounting Policies, during the fourth quarter of 2016, the Company revised the accretion period for its asset retirement obligations from the term of the related PPA agreement to the remaining useful life of the


111




corresponding renewable energy facility, consistent with the period over which depreciation expense is recorded on the corresponding asset retirement cost recognized within renewable energy facilities and with its estimate of the future timing of settlement.

The Company did not have any assets that were legally restricted for the purpose of settling the Company's asset retirement obligations as of December 31, 2017, 2016 and 2015.

8. GOODWILL

Goodwill is recorded as the difference between the aggregate consideration paid for an acquisition and the fair value of the net tangible and identified intangible assets acquired. The Company did not have any goodwill as of December 31, 2017 or 2016.

During 2015, the Company recorded $55.9 million of goodwill attributable to its 2014 acquisition of solar distributed generation facilities from Capital Dynamics, which provided the Company with a scalable distributed generation platform. The goodwill existed within the Company's distributed generation reporting unit within the solar reportable segment and was not deductible for federal income tax purposes. The Company performed its annual impairment test of the carrying value of its goodwill as of December 1, 2016 and concluded that the goodwill balance of $55.9 million was fully impaired. The impairment was driven by a combination of factors, including lack of near-term growth in the operating segment. The impairment test determined there was no implied value of goodwill, which resulted in an impairment charge of $55.9 million as reflected in goodwill impairment within the consolidated statement of operations for the year ended December 31, 2016.

The Company used an income approach methodology of valuation, which used the discounted cash flow method based on forecasted cash flows of the distributed generation reporting unit. The market approach was considered but not used due to the lack of direct similarities with comparable companies in the market.

9. INTANGIBLES

The following table presents the gross carrying amount, accumulated amortization and net book value of intangibles as of December 31, 2017:
(In thousands, except weighted average amortization period)
 
Weighted Average Amortization Period
 
Gross Carrying Amount
 
Accumulated Amortization
 
Net Book Value
Favorable rate revenue contracts
 
15 years
 
$
718,639

 
$
(102,543
)
 
$
616,096

In-place value of market rate revenue contracts
 
19 years
 
521,323

 
(73,104
)
 
448,219

Favorable rate land leases
 
17 years
 
15,800

 
(2,329
)
 
13,471

Total intangible assets, net
 
 
 
$
1,255,762

 
$
(177,976
)
 
$
1,077,786

 
 
 
 
 
 
 
 
 
Unfavorable rate revenue contracts
 
7 years
 
$
35,086

 
$
(16,030
)
 
$
19,056

Unfavorable rate O&M contracts
 
2 years
 
5,000

 
(2,552
)
 
2,448

Unfavorable rate land lease
 
15 years
 
1,000

 
(162
)
 
838

Total intangible liabilities, net
 
 
 
$
41,086

 
$
(18,744
)
 
$
22,342

    


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The following table presents the gross carrying amount, accumulated amortization and net book value of intangibles as of December 31, 2016:
(In thousands, except weighted average amortization period)
 
Weighted Average Amortization Period
 
Gross Carrying Amount
 
Accumulated Amortization
 
Net Book Value
Favorable rate revenue contracts
 
16 years
 
$
714,758

 
$
(57,634
)
 
$
657,124

In-place value of market rate revenue contracts
 
20 years
 
518,003

 
(47,284
)
 
470,719

Favorable rate land leases
 
18 years
 
15,800

 
(1,531
)
 
14,269

Total intangible assets, net
 
 
 
$
1,248,561

 
$
(106,449
)
 
$
1,142,112

 
 
 
 
 
 
 
 
 
Unfavorable rate revenue contracts
 
7 years
 
$
35,086

 
$
(10,541
)
 
$
24,545

Unfavorable rate O&M contracts
 
3 years
 
5,000

 
(1,302
)
 
3,698

Unfavorable rate land lease
 
16 years
 
1,000

 
(107
)
 
893

Total intangible liabilities, net
 
 
 
$
41,086

 
$
(11,950
)
 
$
29,136

    
The Company has intangible assets related to revenue contracts, representing long-term PPAs and REC agreements, and favorable rate land leases that were obtained through acquisitions. The revenue contract intangible assets are comprised of favorable rate PPAs and REC agreements and the in-place value of market rate PPAs. The Company also has intangible liabilities related to unfavorable rate PPAs and REC agreements, unfavorable rate O&M contracts and an unfavorable rate land lease, which are classified within other long-term liabilities in the consolidated balance sheets. These intangible assets and liabilities are amortized on a straight-line basis over the remaining lives of the agreements, which range from 1 to 27 years as of December 31, 2017.

Amortization expense related to favorable rate revenue contracts is reflected in the consolidated statements of operations as a reduction of operating revenues, net. Amortization related to unfavorable rate revenue contracts is reflected in the consolidated statements of operations as an increase to operating revenues, net. During the years ended December 31, 2017, 2016 and 2015, net amortization expense related to favorable and unfavorable rate revenue contracts resulted in a reduction of operating revenues, net of $39.6 million, $40.2 million and $5.3 million, respectively.

Amortization expense related to the in-place value of market rate revenue contracts is reflected in the consolidated statements of operations within depreciation, accretion and amortization expense. During the years ended December 31, 2017, 2016 and 2015, amortization expense related to the in-place value of market rate revenue contracts was $25.5 million, $25.2 million and $18.4 million, respectively.

Amortization expense related to favorable rate land leases is reflected in the consolidated statements of operations within cost of operations. Amortization related to the unfavorable rate land lease and unfavorable rate O&M contracts is reflected in the consolidated statements of operations as a reduction of cost of operations. During the years ended December 31, 2017, 2016 and 2015, net amortization related to favorable and unfavorable rate land leases and unfavorable rate O&M contracts resulted in a $0.5 million and $0.6 million reduction of cost of operations and $0.7 million increase to cost of operations, respectively.



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Over the next five fiscal years, the Company expects to recognize annual amortization on its intangibles as follows:
(In thousands)
 
2018
 
2019
 
2020
 
2021
 
2022
Favorable rate revenue contracts
 
$
44,270

 
$
44,184

 
$
44,184

 
$
42,376

 
$
41,269

Unfavorable rate revenue contracts
 
(4,956
)
 
(4,845
)
 
(2,620
)
 
(1,379
)
 
(1,275
)
Total net amortization expense recorded to operating revenues, net
 
$
39,314

 
$
39,339

 
$
41,564

 
$
40,997

 
$
39,994

 
 
 
 
 
 
 
 
 
 
 
In-place value of market rate revenue contracts
 
$
25,557

 
$
25,557

 
$
25,557

 
$
25,557

 
$
25,552

Total amortization expense recorded to depreciation, accretion and amortization expense
 
$
25,557

 
$
25,557

 
$
25,557

 
$
25,557

 
$
25,552

 
 
 
 
 
 
 
 
 
 
 
Favorable rate land leases
 
$
799

 
$
799

 
$
799

 
$
799

 
$
799

Unfavorable rate O&M contracts
 
(1,250
)
 
(1,198
)
 

 

 

Unfavorable rate land lease
 
(56
)
 
(56
)
 
(56
)
 
(56
)
 
(56
)
Total net amortization recorded to cost of operations
 
$
(507
)
 
$
(455
)
 
$
743

 
$
743

 
$
743


10. VARIABLE INTEREST ENTITIES

The Company consolidates VIEs in renewable energy facilities when the Company is the primary beneficiary. The VIEs own and operate renewable energy facilities in order to generate contracted cash flows. The VIEs were funded through a combination of equity contributions from the owners and non-recourse, project-level debt. As a result of the Company's sale of TerraForm Resi Solar Manager, LLC, a subsidiary of the Company that owned and operated 8.9 MW of residential rooftop solar installations, during the second quarter of 2017, the related assets and liabilities of this variable interest entity were deconsolidated (see Note 4. Assets Held for Sale). No other VIEs were deconsolidated during the years ended December 31, 2017 and 2016.

The carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the Company's consolidated balance sheets are as follows:
 
 
As of December 31,
(In thousands)
 
2017
 
2016
Current assets
 
$
142,403

 
$
191,244

Non-current assets
 
4,155,558

 
4,351,635

Total assets
 
$
4,297,961

 
$
4,542,879

Current liabilities
 
$
119,021

 
$
638,452

Non-current liabilities
 
975,839

 
514,464

Total liabilities
 
$
1,094,860

 
$
1,152,916


The amounts shown in the table above exclude intercompany balances that are eliminated upon consolidation. All of the assets in the table above are restricted for settlement of the VIE obligations, and all of the liabilities in the table above can only be settled by using VIE resources.



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11. LONG-TERM DEBT
    
Long-term debt consists of the following:
 
 
As of December 31,
 
Interest Type
 
Interest Rate (%)1
 
 
(In thousands, except rates)
 
2017
 
2016
 
 
 
Financing Type
Corporate-level long-term debt2:
 
 
 
 
 
 
 
 
 
 
Senior Notes due 2023
 
$

 
$
950,000

 
Fixed
 
N/A
 
Senior notes
New Senior Notes due 2023
 
500,000

 

 
Fixed
 
4.25
 
Senior notes
Senior Notes due 2025
 
300,000

 
300,000

 
Fixed
 
6.63
 
Senior notes
Senior Notes due 2028
 
700,000

 

 
Fixed
 
5.00
 
Senior notes
Revolver
 

 
552,000

 
Variable
 
N/A
 
Revolving loan
New Revolver
 
60,000

 

 
Variable
 
4.38
 
Revolving loan
New Term Loan
 
350,000

 

 
Variable
 
4.15
 
Term debt
Non-recourse long-term debt3:
 
 
 
 
 
 
 
 
 
 
Permanent financing
 
1,616,729

 
2,078,009

 
Blended4
 
5.715
 
Term debt / Senior notes
Financing lease obligations
 
115,787

 
123,930

 
Imputed
 
5.615
 
Financing lease obligations
Total principal due for long-term debt and financing lease obligations
 
3,642,516

 
4,003,939

 
 
 
5.285
 
 
Unamortized discount, net
 
(19,027
)
 
(13,620
)
 
 
 
 
 
 
Deferred financing costs, net
 
(24,689
)
 
(39,405
)
 
 
 
 
 
 
Less current portion of long-term debt and financing lease obligations6
 
(403,488
)
 
(2,212,968
)
 
 
 
 
 
 
Long-term debt and financing lease obligations, less current portion7
 
$
3,195,312

 
$
1,737,946

 
 
 
 
 
 
———
(1)
As of December 31, 2017.
(2)
Outstanding corporate-level debt represents debt issued by Terra Operating LLC and guaranteed by Terra LLC and certain subsidiaries of Terra Operating LLC other than non-recourse subsidiaries as defined in the relevant debt agreements (with the exception of certain unencumbered non-recourse subsidiaries).
(3)
Non-recourse debt represents debt issued by subsidiaries with no recourse to Terra LLC, Terra Operating LLC or guarantors of the Company's corporate-level debt, other than limited or capped contingent support obligations, which in aggregate are not considered to be material to the Company's business and financial condition.
(4)
Includes fixed rate debt and variable rate debt. As of December 31, 2017, 60% of this balance had a fixed interest rate and the remaining 40% of this balance had a variable interest rate. The Company has entered into interest rate swap agreements to fix the interest rates of a majority of the variable rate permanent financing non-recourse debt (see Note 13. Derivatives).
(5)
Represents the weighted average interest rate as of December 31, 2017.
(6)
As of December 31, 2016, the Company reclassified $14.7 million from current portion of long-term debt and financing lease obligations to current liabilities related to assets held for sale in the consolidated balance sheet. There was no similar reclassification as of December 31, 2017 as the sale of the related renewable energy facilities closed in the first half of 2017 (see Note 4. Assets Held for Sale).
(7)
As of December 31, 2016, the Company reclassified $353.9 million from long-term debt and financing lease obligations, less current portion to non-current liabilities related to assets held for sale in the consolidated balance sheet. There was no similar reclassification as of December 31, 2017 as the sale of the related renewable energy facilities closed in the first half of 2017 (see Note 4. Assets Held for Sale).

Corporate-level Long-term Debt

Term Loan
    
On January 28, 2015, Terra Operating LLC repaid the remaining outstanding principal balance on its term loan facility (the “Term Loan”) of $573.5 million. The Company recognized a $12.0 million loss on extinguishment of debt during the year ended December 31, 2015 as a result of this repayment.


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Revolver

On January 28, 2015, Terra Operating LLC replaced its existing revolving credit facility with a new $550.0 million revolving credit facility (the “Revolver”), which was available for revolving loans and letters of credit, and was subsequently increased to a $725.0 million facility over the course of 2015. The Company recognized a $1.3 million loss on extinguishment of debt during the year ended December 31, 2015 as a result of the revolver exchange.
    
During 2016 and 2017, Terra Operating LLC entered into a number of amendments to the terms of the Revolver and obtained certain waivers in regards to extending financial statement reporting deliverable due dates, maintaining compliance with financial maintenance covenants and modifying or obtaining consent regarding certain other provisions. In connection therewith, Terra Operating LLC agreed to permanently reduce the revolving commitments and borrowing capacity under the Revolver by $100.0 million and $105.0 million during 2016 and 2017, respectively, and as a result recognized a $1.1 million loss on extinguishment of debt during both of these years due to the corresponding write-off of a portion of the unamortized deferred financing costs.

At Terra Operating LLC’s option, all outstanding amounts under the Revolver bore interest at a rate per annum equal to either (i) a base rate plus a margin ranging between 1.25% and 1.75% or (ii) a reserve adjusted Eurodollar rate plus a margin ranging between 2.25% and 2.75%, as determined by reference to a leverage-based grid. An amendment the Company entered into on September 9, 2016 increased the interest rate under the Revolver at all applicable margin levels by 50% of the increase in the interest rate on the Senior Notes due 2023 (as defined below) agreed to as part of the consent solicitation process for the Senior Notes due 2023 described below. This amendment resulted in an increase in the interest rate payable under the Revolver by 1.75% for the period from September 6, 2016 to December 6, 2016 and, thereafter, an increase of 0.25%.

On October 17, 2017, concurrently with its entry into the New Revolver (as defined below), Terra Operating LLC terminated the Revolver and repaid the outstanding loan amount of $277.0 million, using $27.0 million of cash on hand and $250.0 million of borrowings drawn under the New Revolver. As a result of this revolver exchange, the Company recognized a $4.5 million loss on extinguishment of debt during the year ended December 31, 2017 due to the write-off of the unamortized deferred financing costs for the Revolver as of the termination date.

New Revolver

On October 17, 2017, Terra Operating LLC entered into a new senior secured revolving credit facility (the “New Revolver”). The New Revolver consists of a revolving credit facility in an initial amount of $450.0 million, available for revolving loans and letters of credit, which Terra Operating LLC subsequently elected to increase to $600.0 million on February 6, 2018. The New Revolver matures on the four-year anniversary of the closing date of such facility. Each of Terra Operating LLC’s existing and subsequently acquired or organized domestic restricted subsidiaries (excluding non-recourse subsidiaries) and Terra LLC are or will become guarantors under the New Revolver. $250.0 million of revolving loans were initially drawn and used to repay a portion of the outstanding borrowings under the existing Revolver as discussed above. Subsequent to the initial issuance, an additional $15.0 million of revolving loans were drawn during the fourth quarter of 2017 and $205.0 million of revolving loans were repaid, primarily using $50.0 million of the proceeds from the issuance of the New Term Loan (as defined below) and $150.0 million of the proceeds from the issuance of the New Senior Notes due 2023 and Senior Notes due 2028 (both defined below).

All outstanding amounts under the New Revolver bear interest at a rate per annum equal to, at Terra Operating LLC’s option, either (i) a base rate plus a margin ranging between 1.25% to 2.00% or (ii) a reserve adjusted Eurodollar rate plus a margin ranging between 2.25% to 3.00%. In addition to paying interest on outstanding principal under the New Revolver, the Company is required to pay a standby fee in respect of the unutilized commitments thereunder, payable quarterly in arrears. This standby fee ranges between 0.375% and 0.50% per annum. The New Revolver provides for voluntary prepayments, in whole or in part, subject to notice periods. There are no prepayment penalties or premiums other than customary breakage costs.

The New Revolver, each guarantee and any interest rate, currency hedging or hedging of REC obligations of Terra Operating LLC or any guarantor owed to the administrative agent, any arranger or any lender under the New Revolver is secured by first priority security interests in (i) all of Terra Operating LLC’s, each guarantor’s and certain unencumbered non-recourse subsidiaries’ assets, (ii) 100% of the capital stock of each of Terra Operating LLC and its domestic restricted


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subsidiaries and 65% of the capital stock of Terra Operating LLC’s foreign restricted subsidiaries and (iii) all intercompany debt. The New Revolver is secured equally and ratably with the New Term Loan (as defined below).

Senior Notes

On January 28, 2015, Terra Operating LLC issued $800.0 million of 5.875% senior notes due 2023 at an offering price of 99.214% of the principal amount. Terra Operating LLC used the net proceeds from the offering to fund a portion of the purchase price payable in the First Wind Acquisition. On June 11, 2015, Terra Operating LLC issued an additional $150.0 million of 5.875% senior notes due 2023 (collectively, with the $800.0 million initially issued, the “Senior Notes due 2023”). The offering price of the additional $150.0 million of notes was 101.5% of the principal amount, and Terra Operating LLC used the net proceeds from the offering to repay existing borrowings under the Revolver.

On July 17, 2015, Terra Operating LLC issued $300.0 million of 6.125% senior notes due 2025 at an offering price of 100% of the principal amount (the “Senior Notes due 2025”). Terra Operating LLC used the net proceeds from the offering to fund a portion of the purchase price of the acquisition of the wind power plants from Invenergy Wind.

During 2016 and 2017, Terra Operating LLC received certain notices of an event of default from the Senior Notes due 2023 and Senior Notes due 2025 trustee for failure to comply with its obligation under the respective indentures to timely file certain of the Company's periodic financial statements, but in each case the Company filed the respective financial statements with the SEC within the grace period for delivery that still applied per the respective indentures (which was extended in one case as discussed directly below), and consequently no events of default occurred with respect to these late filings.

On August 30, 2016, the Company announced the successful completion of a consent solicitation from holders of its Senior Notes due 2023 and its Senior Notes due 2025 to obtain waivers relating to certain reporting covenants (which included an extension of the deadline for filing the Company's 2015 Form 10-K and Form 10-Q for the first quarter of 2016) and to effectuate certain amendments under the respective indentures. Terra Operating LLC received consents from the holders of a majority of the aggregate principal amount of each series of the Senior Notes outstanding as of the record date and paid a consent fee to each consenting holder of $5.00 for each $1,000 principal amount of such series of the Senior Notes for which such holder delivered its consent. Following receipt of the requisite consents, Terra Operating LLC entered into a supplemental indenture for each series of the Senior Notes on August 29, 2016. Effective as of September 6, 2016, these indentures respectively permanently increased the interest rate payable on the Senior Notes due 2023 from 5.875% per annum to 6.375% per annum and the interest rate payable on the Senior Notes due 2025 from 6.125% per annum to 6.625% per annum. In addition, beginning on September 6, 2016 through and including December 6, 2016, special interest accrued on the Senior Notes due 2023 and the Senior Notes due 2025 at a rate equal to 3.0% per annum, which was payable in the same manner as regular interest payments on the first interest payment date following December 6, 2016.

On August 11, 2017, the Company announced the successful completion of another consent solicitation from holders of its Senior Notes due 2023 and its Senior Notes due 2025 to obtain a waiver of the requirement to make an offer to repurchase the Senior Notes issued under the respective indentures (at 101% of the applicable principal amount, plus accrued and unpaid interest) upon the occurrence of the change of control that would result from the consummation of the Merger. Terra Operating LLC received consents from the holders of a majority of the aggregate principal amount of each series of the Senior Notes outstanding as of the record date and paid a consent fee to each consenting holder of $1.25 per $1,000 principal amount of such series of the Senior Notes for which such holder delivered its consent. Upon the closing of the Merger, Terra Operating LLC also paid a success fee of $1.25 per $1,000 principal amount of each series of the Senior Notes for which such consenting holder delivered its consent.

On December 12, 2017, Terra Operating LLC issued $500.0 million of 4.25% senior notes due 2023 at an offering price of 100% of the principal amount (the “New Senior Notes due 2023”) and $700.0 million of 5.00% senior notes due 2028 at an offering price of 100% of the principal amount (the “Senior Notes due 2028”). Terra Operating LLC used the proceeds to redeem in full its existing Senior Notes due 2023, of which $950.0 million remained outstanding, at a redemption price that included a make-whole premium of $50.7 million, plus accrued and unpaid interest, and to repay $150.0 million of revolving loans outstanding under the New Revolver as described above. As a result of the extinguishment of the Company's existing Senior Notes due 2023, the Company recognized a $72.3 million loss on extinguishment of debt during the year ended December 31, 2017, consisting of the $50.7 million make-whole premium and the write-off of $21.6 million of unamortized deferred financing costs and debt discounts for the Senior Notes due 2023 as of the redemption date.



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The New Senior Notes due 2023, Senior Notes due 2025 and Senior Notes due 2028 are senior obligations of Terra Operating LLC and are guaranteed by Terra LLC and each of Terra Operating LLC's subsidiaries that guarantee the New Revolver, the New Term Loan (as defined below) or certain other material indebtedness of Terra Operating LLC or Terra LLC. Each series of the Senior Notes rank equally in right of payment with all existing and future senior indebtedness of Terra Operating LLC, including the New Revolver and the New Term Loan, senior in right of payment to any future subordinated indebtedness of Terra Operating LLC, and effectively subordinated to all borrowings under the New Revolver and the New Term Loan, which are secured by substantially all of the assets of Terra Operating LLC and the guarantors of the Senior Notes.

At its option, Terra Operating LLC may redeem some or all of each series of the Senior Notes at any time or from time to time prior to their maturity. If Terra Operating LLC elects to redeem the New Senior Notes due 2023 prior to October 31, 2022 or the Senior Notes due 2028 prior to July 31, 2027, Terra Operating LLC would be required to pay a make-whole premium as set forth in the applicable indenture. If Terra Operating LLC elects to redeem the New Senior Notes due 2023 or the Senior Notes due 2028 on or after these respective dates, Terra Operating LLC would be required to pay a redemption price equal to 100% of the aggregate principal amount of the Senior Notes redeemed plus accrued and unpaid interest thereon. If Terra Operating LLC elects to redeem the Senior Notes due 2025 prior to June 15, 2020, it would be required to pay a make-whole premium as set forth in the indenture. If Terra Operating LLC elects to redeem the Senior Notes due 2025 on or after June 15, 2020 but prior to June 15, 2023, it would be required pay a redemption premium that includes a premium to par adjustment as set forth in the indenture, and if Terra Operating LLC elects to redeem the Senior Notes due 2025 on or after June 15, 2023, it would be required to pay a redemption price equal to 100% of the aggregate principal amount of the Senior Notes redeemed plus accrued and unpaid interest thereon. If certain change of control triggering events occur in the future, Terra Operating LLC must offer to repurchase all of each series of the Senior Notes at a price equal to 101% of the principal amount thereof, plus accrued and unpaid interest, if any, to the repurchase date.

Sponsor Line Agreement

On October 16, 2017, TerraForm Power entered into a credit agreement (the “Sponsor Line Agreement”) with Brookfield and one of its affiliates. The Sponsor Line Agreement establishes a $500.0 million secured revolving credit facility and provides for the lenders to commit to make LIBOR loans to the Company during a period not to exceed three years from the effective date of the Sponsor Line Agreement (subject to acceleration for certain specified events). The Company may only use the revolving credit facility to fund all or a portion of certain funded acquisitions or growth capital expenditures. The Sponsor Line Agreement will terminate, and all obligations thereunder will become payable, no later than October 16, 2022. As of December 31, 2017, there were no amounts drawn under the Sponsor Line Agreement.

Borrowings under the Sponsor Line Agreement will bear interest at a rate per annum equal to a LIBOR rate determined by reference to the costs of funds for U.S. dollar deposits for the interest period relevant to such borrowing adjusted for certain additional costs, in each case plus 3.00% per annum. In addition to paying interest on outstanding principal under the Sponsor Line Agreement, the Company is required to pay a standby fee of 0.50% per annum in respect of the unutilized commitments thereunder, payable quarterly in arrears.

TerraForm Power will be permitted to voluntarily reduce the unutilized portion of the commitment amount and repay outstanding loans under the Sponsor Line Agreement at any time without premium or penalty, other than customary “breakage” costs. TerraForm Power’s obligations under the Sponsor Line Agreement are secured by first-priority security interests in substantially all assets of TerraForm Power, including 100% of the capital stock of Terra LLC, in each case subject to certain exclusions set forth in the credit documentation governing the Sponsor Line Agreement.

New Term Loan

On November 8, 2017, Terra Operating LLC entered into a 5-year $350.0 million senior secured term loan (the “New Term Loan”), which was used to repay outstanding borrowings under the Midco Portfolio Term Loan (as defined and discussed below) and $50.0 million of revolving loans outstanding under the New Revolver. The New Term Loan bears interest at a rate per annum equal to, at Terra Operating LLC's option, either (i) a base rate plus a margin of 1.75% or (ii) a reserve adjusted Eurodollar rate plus a margin of 2.75%, and is secured and guaranteed equally and ratably with the New Revolver. The New Term Loan provides for voluntary prepayments, in whole or in part, subject to notice periods. There are no prepayment penalties or premiums other than customary breakage costs subsequent to the six-month anniversary of the closing date. Within the first six months following the closing date, a prepayment premium of 1.00% would apply to any principal amounts that were prepaid.


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Covenants and Cross-defaults    

The terms of the Company's corporate-level debt agreements and indentures include customary affirmative and negative covenants and provide for customary events of default, which include, among others, nonpayment of principal or interest and failure to timely deliver financial statements. This includes quarterly financial maintenance covenants for the New Revolver. The occurrence of an event of default for one corporate-level debt instrument could also cause a cross-default for the other respective corporate-level debt instruments as described below.

Pursuant to both the terms of the New Revolver and the New Term Loan, a default of more than $75.0 million of indebtedness (other than non-recourse indebtedness, and indebtedness under the Sponsor Line Agreement, which is an obligation of TerraForm Power), including under these respective agreements, would result in a cross-default under the respective agreements that would permit the lenders holding more than 50% of the aggregate exposure under each to accelerate any outstanding principal amount of loans, terminate any outstanding letter of credit and terminate the outstanding commitments (as applicable to each).
    
Pursuant to the terms of each series of the Senior Notes, a default of indebtedness that exceeds the greater of $100.0 million or 1.5% of the Company’s consolidated total assets (other than non-recourse indebtedness and indebtedness under the Sponsor Line Agreement, which is an obligation of TerraForm Power), that is (i) caused by a failure to pay principal of, or interest or premium, if any, on such indebtedness prior to the expiration of the grace period provided in such indebtedness on the date of such default or (ii) results in the acceleration of such indebtedness would give the trustee under the respective indentures or the holders of at least 25% in the aggregate principal amount of the then outstanding Senior Notes under the respective indentures the right to accelerate any outstanding principal amount of loans and terminate the outstanding commitments under the respective indentures.

An event of default of more than $75.0 million of indebtedness under the New Revolver, New Term Loan and each series of the Senior Notes would trigger an event of default under the Sponsor Line Agreement that would permit the lenders to accelerate any outstanding principal amount of loans and terminate the outstanding commitments under the Sponsor Line Agreement.

Non-recourse Long-term Debt

Indirect subsidiaries of the Company have incurred long-term non-recourse debt obligations with respect to the renewable energy facilities that those subsidiaries own directly or indirectly. The indebtedness of these subsidiaries is typically secured by the renewable energy facility's assets (mainly the renewable energy facility) or equity interests in subsidiaries that directly or indirectly hold renewable energy facilities with no recourse to TerraForm Power, Terra LLC or Terra Operating LLC other than limited or capped contingent support obligations, which in aggregate are not considered to be material to the Company's business and financial condition. In connection with these financings and in the ordinary course of its business, the Company and its subsidiaries observe formalities and operating procedures to maintain each of their separate existence and can readily identify each of their separate assets and liabilities as separate and distinct from each other. As a result, these subsidiaries are legal entities that are separate and distinct from TerraForm Power, Terra LLC, Terra Operating LLC and the guarantors under the New Revolver, the New Senior Notes due 2023, the Senior Notes due 2025, the Senior Notes due 2028, the Sponsor Line Agreement and the New Term Loan.

U.K. Debt Refinancing

On November 6, 2015, the Company entered into definitive agreements to refinance GBP 178.6 million (equivalent of $270.8 million on the closing date) of existing non-recourse indebtedness by entering into a new GBP 313.5 million (equivalent of $475.2 million on the closing date) facility. The new facility was comprised of Tranche A for GBP 87.0 million (equivalent of $131.9 million) which was fully amortizing over the seven-year term, and Tranche B for GBP 226.5 million (equivalent of $343.3 million), which was payable at maturity in 2022. This new facility bore interest at a rate per annum equal to LIBOR plus an applicable margin of 2.10% for Tranche A and 2.35% for Tranche B. The non-recourse facility was secured by all of the Company's solar generation facilities located in the U.K. except for the Norrington facility. The Company recognized a loss on extinguishment of debt of $7.5 million during the year ended December 31, 2015 as a result of this refinancing. As discussed in Note 4. Assets Held for Sale, Terra Operating LLC closed on its sale of the U.K. Portfolio on May 11, 2017 to Vortex Solar UK Limited, which resulted in the reduction of this indebtedness.


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Non-recourse Portfolio Term Loan

A wholly owned subsidiary of the Company entered into a $500.0 million non-recourse portfolio term loan commitment that was funded on December 15, 2015 (the “Midco Portfolio Term Loan”) and a majority of the proceeds were used to acquire wind power plants from Invenergy Wind. Interest under the term loan accrued at a rate equal to an adjusted Eurodollar rate plus 5.5%, subject to a 1.0% LIBOR floor (or base rate plus 4.5%). The term loan was secured by indirect equity interests in approximately 1,104.3 MW of the Company's renewable energy facilities, consisting of assets acquired from Invenergy Wind and certain other renewable energy facilities acquired from SunEdison, and was to mature on January 15, 2019, to the extent the Company exercised its extension options. The Company exercised the first two extension options in January and July of 2017, respectively.

In June of 2017, the Company agreed to make a $100.0 million prepayment for this loan in connection with obtaining (i) a waiver to extend the 2016 audited project financial statement deadline under the loan agreement and (ii) a waiver of the change of control default that would arise under this loan agreement as a result of the Merger until, in the case of the change of control waiver, the date that is the earlier of three months following the closing of the Merger and March 31, 2018. This prepayment was made using a portion of the proceeds the Company received from the sale of the U.K. Portfolio as discussed in Note 4. Assets Held for Sale. The Company made approximately $68 million of additional prepayments in the second half of 2017 and repaid the remaining principal balance of $300.0 million on November 8, 2017 using borrowings from the New Term Loan that was entered into on that date as discussed above. The Company recognized a $3.2 million loss on extinguishment of debt during the year ended December 31, 2017 as a result of these prepayments and final repayment.

Canada Project-level Financing

On November 2, 2016, certain of the Company's subsidiaries entered into a new non-recourse loan financing in an aggregate principal amount of CAD $120.0 million (including a CAD $6.9 million letter of credit) secured by approximately 59 MW of utility-scale solar power plants located in Canada that are owned by the Company's subsidiaries. The proceeds of this financing were used to pay down the Revolver by $70.0 million and were used for general corporate purposes. On February 28, 2017, the Company increased the principal amount of the credit facility by an additional CAD $113.9 million (including an additional CAD $6.7 million letter of credit), increasing the total facility to CAD $233.9 million. The proceeds of this additional financing were primarily used for general corporate purposes. This non-recourse loan has a seven-year maturity and amortizes on a 17-year sculpted amortization schedule.

Non-recourse Debt Defaults

Over the course of 2016 and 2017, the Company experienced defaults in its non-recourse debt financings that principally arose as a result of the filing for bankruptcy of certain SunEdison Debtors that served as providers of O&M or asset management services to its renewable energy facilities (or as guarantors of those service providers) and as a result of the failure of the applicable subsidiary or the Company to timely deliver audited or unaudited financial statements and other deliverables required by the applicable financing arrangements. With the exception of its 101.6 MW renewable energy facility in Chile, to date the Company has transitioned all the project-level services provided by SunEdison Debtors to third parties or in-house to a Company affiliate. The Company has also delivered all outstanding Company and project-level financial statements and deliverables as of the date hereof, has substantially obtained all waivers needed for late delivery of financial statements that were delivered after the grace period expired and expects to complete its project-level audits for fiscal year 2017 within the time periods (taking into account the respective grace periods) for their delivery.

As a result of non-recourse debt defaults that were outstanding as of the financial statement issuance date for the Company’s 2016 Form 10-K, the Company reclassified $1.6 billion of the Company's non-recourse long-term indebtedness, net of unamortized debt discounts and deferred financing costs, to current in the consolidated balance sheet as of December 31, 2016. The Company reclassified these amounts because at that time the applicable contractual grace periods had already expired or the Company could not assert that it was probable that the default would be cured within any remaining grace periods, and the lender had not waived or subsequently lost the right to demand repayment for more than one year from the balance sheet date. The Company accounts for debt in default as of the date the financial statements are issued in the same manner as if the default existed as of the balance sheet date. As of December 31, 2017, the Company reclassified $239.7 million of non-recourse long-term indebtedness to current in the consolidated balance sheet due to defaults still existing as of the date of the issuance of these financial statements, which primarily consisted of indebtedness of the Company's renewable energy


120


facility in Chile.

The Company continued to amortize deferred financing costs and debt discounts over the maturities of the respective financing agreements as before the violations, as the Company believed there was a reasonable likelihood that it would be able to successfully negotiate a waiver with the lenders and/or cure the defaults. The Company based this conclusion on (i) its past history of obtaining waivers and/or forbearance agreements with lenders, (ii) the nature and existence of active negotiations between the Company and the respective lenders to secure a waiver, (iii) ongoing efforts to cure certain of the defaults, (iv) the Company's timely servicing of these debt instruments and (v) the fact that no non-recourse financing has been accelerated to date and no project-level lender has notified the Company of such lenders election to enforce project security interests.

Refer to Note 2. Summary of Significant Accounting Policies and Note 13. Derivatives, respectively, for discussion of corresponding restricted cash and interest rate swap reclassifications to current as a result of these defaults.

Financing Lease Obligations

In certain transactions, the Company accounts for the proceeds of sale-leasebacks as financings, which are typically secured by the renewable energy facility asset and its future cash flows from energy sales, with no recourse to Terra LLC or Terra Operating LLC under the terms of the arrangement.

As a result of the First Wind Acquisition, the Company acquired $47.4 million of financing lease obligations. The financing lease obligations assumed by the Company include those pursuant to a sale-leaseback agreement, entered into by First Wind on November 21, 2012, whereby First Wind sold substantially all of the property, plant and equipment of the related wind power plant to a financial institution and simultaneously entered into a long-term lease with that financial institution for the use of the assets. Under the terms of the agreement, the Company will continue to operate the wind facility and has the option to extend the lease or repurchase the assets sold at the end of the lease term.

On May 22, 2015, SunEdison acquired the lessor interest in an operating solar generation facility referred to as the Duke Energy operating facility and concurrently sold the facility to the Company. Upon acquisition of this operating facility, the Company recognized a net gain on the extinguishment of debt of $11.4 million during the year ended December 31, 2015 due to the termination of $31.5 million of financing lease obligations of the operating facility.

First Wind Debt Extinguishment
    
The Company repaid certain long-term indebtedness for the renewable energy facilities acquired as part of the First Wind Acquisition. The Company recognized a loss on the extinguishment of debt of $6.4 million during the year ended December 31, 2015 as a result of this repayment.

Minimum Lease Payments

The aggregate amounts of minimum lease payments on the Company's financing lease obligations are $115.8 million. Contractual obligations for 2018 through 2022 and thereafter, are as follows:
(In thousands)
2018
 
2019
 
2020
 
2021
 
2022
 
Thereafter
 
Total
Minimum lease obligations1
$
9,852

 
$
19,108

 
$
9,218

 
$
9,130

 
$
5,700

 
$
62,779

 
$
115,787

———
(1)
Represents the minimum lease payment due dates for the Company's financing lease obligations and does not reflect the reclassification of $39.4 million of financing lease obligations to current as a result of debt defaults under certain of the Company's non-recourse financing arrangements.



121


Maturities

The aggregate contractual payments of long-term debt due after December 31, 2017, excluding financing lease obligations and amortization of debt discounts, premiums and deferred financing costs, as stated in the financing agreements, are as follows:
(In thousands)
20181
 
2019
 
2020
 
2021
 
2022
 
Thereafter
 
Total
Maturities of long-term debt as of December 31, 20172
$
152,745

 
$
91,404

 
$
96,087

 
$
99,278

 
$
591,032

 
$
2,496,183

 
$
3,526,729

———
(1)
Includes $60.0 million of New Revolver indebtedness, of which the Company repaid $42.0 million with cash on hand in the first quarter of 2018.
(2)
Represents the contractual principal payment due dates for the Company's long-term debt and does not reflect the reclassification of $200.3 million of long-term debt to current as a result of debt defaults under certain of the Company's non-recourse financing arrangements.

12. INCOME TAXES

The income tax provision consisted of the following:
(In thousands)
 
Current
 
Deferred
 
Total
Year ended December 31, 2017
 
 
 
 
 
 
U.S. federal
 
$
(45
)
 
$
(23,928
)
 
$
(23,973
)
State and local
 
95

 
(1,211
)
 
(1,116
)
Foreign
 
220

 
1,789

 
2,009

Total expense (benefit)
 
$
270

 
$
(23,350
)
 
$
(23,080
)
Tax expense in equity
 

 
14,081

 
14,081

Total
 
$
270

 
$
(9,269
)
 
$
(8,999
)
 
 
 
 
 
 
 
Year ended December 31, 2016
 
 
 
 
 
 
U.S. federal
 
$
66

 
$
(103
)
 
$
(37
)
State and local
 
53

 
(1,109
)
 
(1,056
)
Foreign
 

 
1,587

 
1,587

Total expense
 
$
119

 
$
375

 
$
494

Tax expense in equity
 

 
406

 
406

Total
 
$
119

 
$
781

 
$
900

 
 
 
 
 
 
 
Year ended December 31, 2015
 
 
 
 
 
 
U.S. federal
 
$
98

 
$
(12,507
)
 
$
(12,409
)
State and local
 

 
(1,182
)
 
(1,182
)
Foreign
 
158

 
192

 
350

Total expense (benefit)
 
$
256

 
$
(13,497
)
 
$
(13,241
)
Tax expense in equity
 

 
14,627

 
14,627

Total
 
$
256

 
$
1,130

 
$
1,386




122


Effective Tax Rate

The income tax provision differed from the amounts computed by applying the statutory U.S. federal income tax rate of 35% to loss before income taxes, as follows:
 
 
Year Ended December 31,
 
 
2017
 
2016
 
2015
Income tax benefit at U.S. federal statutory rate
 
35.0
 %
 
35.0
 %
 
35.0
 %
Increase (reduction) in income taxes:
 
 
 
 
 
 
State income taxes, net of U.S. federal benefit
 
4.0

 
(5.9
)
 
1.0

Foreign operations
 
8.7

 
(1.5
)
 
9.9

Non-controlling interest
 
(9.4
)
 
(15.9
)
 
(20.6
)
Goodwill impairment
 

 
(6.2
)
 

Stock-based compensation
 

 

 
(2.2
)
Tax Act rate change impact
 
2.0

 

 

Change in valuation allowance
 
(34.1
)
 
(4.7
)
 
(17.7
)
Other
 
2.8

 
(1.0
)
 
0.6

Effective tax rate
 
9.0
 %
 
(0.2
)%
 
6.0
 %
        
Prior to the consummation of the Merger on October 16, 2017, TerraForm Power owned approximately 66% of Terra LLC and SunEdison owned approximately 34% of Terra LLC. On October 16, 2017, pursuant to the Settlement Agreement, SunEdison transferred its interest in Terra LLC to TerraForm Power. As a result of this transaction, TerraForm Power now owns 100% of the capital and profits interest in Terra LLC, except for the IDRs which are owned by Brookfield IDR Holder.

Terraform Power consolidates the results of Terra LLC through its controlling interest. Prior to the consummation of the Merger, it recorded SunEdison's ownership of Terra LLC as a non-controlling interest in the financial statements. Terra LLC is treated as a partnership for income tax purposes. As such, the Company recorded income tax on its share of Terra LLC's taxable income and SunEdison recorded income tax on its share of Terra LLC's taxable income in accordance with the applicable ownership percentages before and after the Merger on October 16, 2017.

For the year ended December 31, 2017, the overall effective tax rate was different than the statutory rate of 35% primarily due to loss allocated to the recording of a valuation allowance on certain tax benefits attributed to the Company, loss
allocated to non-controlling interests, the revaluation of deferred federal and state tax balances and the effect of foreign and state taxes. For the year ended December 31, 2016, the overall effective tax rate was different than the statutory rate of 35% primarily due to loss allocated to the recording of a valuation allowance on certain tax benefits attributed to the Company, loss allocated to non-controlling interests, the impairment of goodwill at Capital Dynamics and the effect of state taxes. For the year ended December 31, 2015, the overall effective tax rate was different than the statutory rate of 35% primarily due to the recording of a valuation allowance on certain tax benefits attributed to the Company, loss allocated to non-controlling interests and due to the application of the intraperiod allocation rules, resulting in a significant tax provision recorded in other comprehensive income. As of December 31, 2017 and 2016, most jurisdictions were in a net deferred tax asset position. A valuation allowance is recorded against the deferred tax assets primarily because of the history of losses in those jurisdictions.



123


The tax effects of the major items recorded as deferred tax assets and liabilities were as follows:
 
 
As of December 31,
(In thousands)
 
2017
 
2016
Deferred tax assets:
 
 
 
 
Net operating losses and tax credit carryforwards
 
$
402,162

 
$
463,940

Deferred revenue
 

 
743

Other
 

 
5,445

Total deferred tax assets
 
402,162

 
470,128

Valuation allowance
 
(152,142
)
 
(419,875
)
Net deferred tax assets
 
250,020

 
50,253

Deferred tax liabilities:
 
 
 
 
Investment in partnership
 
234,312

 
73,629

Renewable energy facilities
 
29,541

 
4,347

Deferred revenue
 
13

 

Other
 
4,790

 

Total deferred tax liabilities
 
268,656

 
77,976

Net deferred tax liabilities
 
$
18,636

 
$
27,723

    
The underlying renewable energy facilities are controlled under Terra LLC, and thus deferred tax assets and liabilities at the Company's portfolio companies are captured within the deferred tax asset for investment in partnership. The Company has gross net operating loss carryforwards of $1.4 billion in the U.S. and gross net operating loss carryforwards of $138.4 million in foreign jurisdictions that will both expire beginning in 2035. The Company believes that it is more likely than not that it will not generate sufficient taxable income to realize the deferred tax assets associated with its net operating losses and tax credit carryforwards and has recorded a valuation allowance against its deferred tax assets, with the exception of $31.4 million of net operating losses at its Canadian operations. The Company is currently performing an analysis of limitations on the use of net operating losses under Section 382. The results of this analysis may impact the Company's ability to utilize portions of its net operating losses in future periods or could reduce the net operating losses available for carryover and utilization in future periods.

The decrease in the valuation allowance during 2017 was primarily driven by a $75.9 million decrease resulting from the reduction of the U.S. federal tax rate to 21% due to the enactment of the Tax Act, a $43.0 million U.S. return to provision adjustment and a $150.0 million decrease related to an offsetting adjustment to deferred tax liabilities to correct the outside basis in the partnership.

During the fourth quarter of 2017, management identified an immaterial error resulting from the ownership percentages used to allocate lower-tier partnership income to a subsidiary of the Company included in the U.S. tax provision. The error caused an overstatement of taxable income used in the income tax provision calculation in 2016 of approximately $16.2 million, which resulted in an error in the income tax provision. This 2016 error was corrected in the fourth quarter of 2017, which resulted in an increase to the net operating loss carryforward deferred tax asset at the corresponding subsidiary and an offsetting $6.4 million increase in the income tax benefit recognized. Management determined that this error did not have an impact on its previously issued filings for the first, second and third quarter of 2017.
    
As of December 31, 2017 and 2016, the Company had not identified any uncertain tax positions for which a liability was required.



124


13. DERIVATIVES

As part of the Company’s risk management strategy, the Company has entered into derivative instruments which include interest rate swaps, foreign currency contracts and commodity contracts to mitigate interest rate, foreign currency and commodity price exposure. If the Company elects to do so and if the instrument meets the criteria specified in ASC 815, Derivatives and Hedging, the Company designates its derivative instruments as cash flow hedges. The Company enters into interest rate swap agreements in order to hedge the variability of expected future cash interest payments. Foreign currency contracts are used to reduce risks arising from the change in fair value of certain foreign currency denominated assets and liabilities. The objective of these practices is to minimize the impact of foreign currency fluctuations on operating results. The Company also enters into commodity contracts to economically hedge price variability inherent in electricity sales arrangements. The objectives of the commodity contracts are to minimize the impact of variability in spot electricity prices and stabilize estimated revenue streams. The Company does not use derivative instruments for speculative purposes.

As of December 31, 2017 and 2016, fair values of the following derivative instruments were included in the balance sheet captions indicated below:
 
 
Fair Value of Derivative Instruments
 
 
 
 
 
 
 
 
Hedging Contracts
 
Derivatives Not Designated as Hedges
 
 
 
 
 
 
(In thousands)
 
Interest Rate Swaps
 
Commodity Contracts
 
Interest Rate Swaps
 
Foreign Currency Contracts
 
Commodity Contracts
 
Gross Amounts of Assets/Liabilities Recognized
 
Gross Amounts Offset in Consolidated Balance Sheet
 
Net Amounts in Consolidated Balance Sheet
As of December 31, 2017
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Prepaid expenses and other current assets
 
$

 
$
8,961

 
$

 
$
63

 
$
12,609

 
$
21,633

 
$
(63
)
 
$
21,570

Other assets
 
4,686

 
71,307

 

 

 
14,787

 
90,780

 

 
90,780

Total assets
 
$
4,686

 
$
80,268

 
$

 
$
63

 
$
27,396

 
$
112,413

 
$
(63
)
 
$
112,350

Accounts payable, accrued expenses and other current liabilities
 
$
2,490

 
$

 
$
197

 
$
99

 
$

 
$
2,786

 
$
(63
)
 
$
2,723

Other long-term liabilities
 
4,796

 

 
404

 

 

 
5,200

 

 
5,200

Total liabilities
 
$
7,286

 
$

 
$
601

 
$
99

 
$

 
$
7,986

 
$
(63
)
 
$
7,923

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
As of December 31, 2016
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Prepaid expenses and other current assets
 
$
1,150

 
$
3,664

 
$

 
$
953

 
$
12,028

 
$
17,795

 
$

 
$
17,795

Other assets
 
411

 
62,474

 

 
460

 
25,167

 
88,512

 

 
88,512

Total assets
 
$
1,561

 
$
66,138

 
$

 
$
1,413

 
$
37,195

 
$
106,307

 
$

 
$
106,307

Accounts payable, accrued expenses and other current liabilities
 
$
10,689

 
$

 
$
814

 
$

 
$

 
$
11,503

 
$

 
$
11,503

Liabilities related to assets held for sale
 

 

 
4,041

 

 

 
4,041

 

 
4,041

Other long-term liabilities
 
47

 

 

 

 

 
47

 

 
47

Non-current liabilities related to assets held for sale
 

 

 
16,786

 

 

 
16,786

 

 
16,786

Total liabilities
 
$
10,736

 
$

 
$
21,641

 
$

 
$

 
$
32,377

 
$

 
$
32,377




125


As of December 31, 2017 and 2016, notional amounts for derivative instruments consisted of the following:
 
 
Notional Amount as of December 31,
(In thousands)
 
2017
 
2016
Derivatives designated as hedges:
 
 
 
 
Interest rate swaps (USD)
 
395,986

 
433,874

Interest rate swaps (CAD)
 
156,367

 
84,713

Commodity contracts (MWhs)
 
15,579

 
16,988

Derivatives not designated as hedges:
 
 
 
 
Interest rate swaps (USD)
 
13,520

 
14,681

Interest rate swaps (GBP)
 

 
222,018

Foreign currency contracts (CAD)
 
9,875

 
25,075

Commodity contracts (MWhs)
 
987

 
1,407


The Company has elected to present net derivative assets and liabilities on the balance sheet as a right to setoff exists. For interest rate swaps, the Company either nets derivative assets and liabilities on a trade-by-trade basis or nets them in accordance with a master netting arrangement if such an arrangement exists with the counterparties. Foreign currency contracts are netted by currency in accordance with a master netting arrangement. The Company has a master netting arrangement for its commodity contracts for which no amounts were netted as of December 31, 2017 or 2016 as each of the commodity contracts were in a gain position.

Gains and losses on derivatives not designated as hedges for the years ended December 31, 2017, 2016 and 2015 consisted of the following:
 
 
Location of Loss (Gain) in the Statements of Operations
 
Year Ended December 31,
(In thousands)
2017
 
2016
 
2015
Interest rate swaps
 
Interest expense, net
 
$
3,161

 
$
26,280

 
$
345

Foreign currency contracts
 
(Gain) loss on foreign currency exchange, net
 
966

 
(1,325
)
 
(3,600
)
Commodity contracts
 
Operating revenues, net
 
(5,117
)
 
(10,890
)
 
(10,178
)
    
During the second quarter of 2016, the Company discontinued hedge accounting for interest rate swaps that were previously designated as cash flow hedges of the forecasted interest payments pertaining to variable rate project debt in the U.K. Portfolio. Hedge accounting was prospectively discontinued for interest payments occurring before the anticipated sale date of June 2017, and for periods beyond that, the losses of $16.9 million accumulated in other comprehensive income were fully reclassified into interest expense, net during the second quarter of 2016. Subsequent to the discontinuation of hedge accounting, the Company recognized additional net unrealized losses of $7.3 million pertaining to these interest rate swaps during the year ended December 31, 2016 that are also reported in interest expense, net in the consolidated statement of operations.

As discussed in Note 4. Assets Held for Sale, the Company consummated the sale of the U.K. Portfolio on May 11, 2017. As part of the sale agreement, Vortex Solar UK Limited assumed the debt and the associated interest rate swaps. As of the date of the sale, the remaining loss amount accumulated in other comprehensive income of $0.4 million was reclassified into interest expense, net, and the fair value of the interest rate swap liability of $23.4 million is reflected within gain on sale of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2017. The interest expense amount reflected in the table above for the year ended December 31, 2017 primarily pertains to these interest rate swaps.



126


Gains and losses recognized related to derivatives designated as cash flow hedges for the years ended December 31, 2017, 2016 and 2015 consisted of the following:
 
 
Year Ended December 31,
 
 
(Loss) Gain Recognized in Other Comprehensive Income (Effective Portion) net of taxes1
 
Location of Amount Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion)
 
Amount of Loss (Gain) Reclassified from Accumulated Other Comprehensive Income into Income (Effective Portion)2
 
Amount of Loss (Gain) Recognized in Income (Ineffective Portion and Amount Excluded from Effectiveness Testing)
(In thousands)
 
2017
 
2016
 
2015
 
 
2017
 
2016
 
2015
 
2017
 
2016
 
2015
Interest rate swaps
 
$
(396
)
 
$
(20,360
)
 
$
(11,482
)
 
Interest expense, net
 
$
5,507

 
$
11,618

 
$
4,663

 
$
(1,270
)
 
$

 
$

Commodity contracts
 
18,008

 
20,274

 
38,395

 
Operating revenues, net
 
(7,754
)
 
(12,572
)
 

 
(2,923
)
 
5,121

 

Total
 
$
17,612

 
$
(86
)
 
$
26,913

 
 
 
$
(2,247
)
 
$
(954
)
 
$
4,663

 
$
(4,193
)
 
$
5,121

 
$

————
(1)
Net of tax benefit of $0.1 million attributed to interest rate swaps during the year ended December 31, 2017 and tax expense of $2.5 million, $0.4 million and $14.6 million attributed to commodity contracts during the years ended December 31, 2017, 2016 and 2015, respectively. There were no taxes attributed to interest rate swaps during the years ended December 31, 2016 and 2015.
(2)
Net of tax benefit of $1.1 million and tax expense of $1.5 million attributed to interest rate swaps and commodity contracts during the year ended December 31, 2017, respectively. There were no taxes attributed to derivatives designated as cash flow hedges during the years ended December 31, 2016 and 2015.

As of December 31, 2017 and 2016, the Company had posted letters of credit in the amount of $15.0 million and $18.0 million, respectively, as collateral related to certain commodity contracts. Certain derivative contracts contain provisions providing the counterparties a lien on specific assets as collateral. There was no cash collateral received or pledged as of December 31, 2017 and 2016 related to the Company's derivative transactions.

Derivatives Designated as Hedges

Interest Rate Swaps

The Company has interest rate swap agreements to hedge variable rate non-recourse debt. These interest rate swaps qualify for hedge accounting and were designated as cash flow hedges. Under the interest rate swap agreements, the renewable energy facilities pay a fixed rate and the counterparties to the agreements pay a variable interest rate. The amounts deferred in other comprehensive income and reclassified into earnings during the years ended December 31, 2017, 2016 and 2015 related to these interest rate swaps are provided in the tables above. The loss expected to be reclassified into earnings over the next twelve months is approximately $1.4 million. The maximum term of outstanding interest rate swaps designated as hedges is 16 years.

As discussed in Note 11. Long-term Debt, the Company experienced defaults under certain of its non-recourse financing agreements. As the Company's interest rate swap agreements contain cross-default provisions, $4.8 million of related liabilities were reclassified to current as of December 31, 2016. There was no similar reclassification for these interest rate swaps as of December 31, 2017 as the defaults under the corresponding financing agreements were cured and/or waived prior to the issuance of the financial statements. The Company did not expect any changes to the underlying cash flows as a result of the defaults that existed in the prior year and thus determined that there was no impact to the swaps' qualification for hedge accounting and designation as cash flow hedges.

Commodity Contracts

The Company has long-dated physically delivered commodity contracts that hedge variability in cash flows associated with the sales of power from certain renewable energy facilities located in Texas. These commodity contracts qualify for hedge accounting and are designated as cash flow hedges. Accordingly, the effective portions of the change in fair value of these derivatives are reported in accumulated other comprehensive income and subsequently reclassified to earnings in the periods when the hedged transactions affect earnings. Any ineffective portions of the derivatives’ change in fair value are recognized currently in earnings. The amounts deferred in other comprehensive income and reclassified into earnings during the years ended December 31, 2017, 2016 and 2015 related to these commodity contracts are provided in the tables above. The gain


127


expected to be reclassified into earnings over the next twelve months is approximately $9.4 million. The maximum term of outstanding commodity contracts designated as hedges is 12 years.

Derivatives Not Designated as Hedges

Interest Rate Swaps

The Company has interest rate swap agreements that economically hedge the cash flows for non-recourse debt. These interest rate swaps pay a fixed rate and the counterparties to the agreements pay a variable interest rate. The changes in fair value are recorded in interest expense, net in the consolidated statements of operations as these hedges are not accounted for under hedge accounting.

As discussed in Note 11. Long-term Debt, the Company experienced defaults under certain of its non-recourse financing agreements. As the Company's interest rate swap agreements contain cross-default provisions, $0.5 million of related liabilities were reclassified to current as of December 31, 2016. There was no similar reclassification for these interest rate swaps as of December 31, 2017 as the defaults under the corresponding financing agreements were cured and/or waived prior to the issuance of the financial statements.

As of December 31, 2016, the Company reclassified $4.0 million of current derivative liabilities to liabilities related to assets held for sale and $16.8 million of non-current derivative liabilities to non-current liabilities related to assets held for sale. These pertained to interest rate swap agreements for the U.K. Portfolio. There was no similar reclassification as of December 31, 2017 as the sale of the related renewable energy facilities closed in the first half of 2017. The Company discontinued hedge accounting for these interest rate swaps during the second quarter of 2016 as discussed above.

Foreign Currency Contracts

The Company has foreign currency contracts in order to economically hedge its exposure to foreign currency fluctuations. The settlement of these hedges occurs on a quarterly basis through maturity. As these hedges are not accounted for under hedge accounting, the changes in fair value are recorded in (gain) loss on foreign currency exchange, net in the consolidated statements of operations.

Commodity Contracts

The Company has commodity contracts in order to economically hedge commodity price variability inherent in certain electricity sales arrangements. If the Company sells electricity to an independent system operator market and there is no PPA available, it may enter into a commodity contract to hedge all or a portion of their estimated revenue stream. These commodity contracts require periodic settlements in which the Company receives a fixed-price based on specified quantities of electricity and pays the counterparty a variable market price based on the same specified quantity of electricity. As these hedges are not accounted for under hedge accounting, the changes in fair value are recorded in operating revenues, net in the consolidated statements of operations.

14. FAIR VALUE OF FINANCIAL INSTRUMENTS

The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. The Company uses valuation techniques that maximize the use of observable inputs. Assets and liabilities are classified in their entirety based on the lowest priority level of input that is significant to the fair value measurement. Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. If the inputs into the valuation are not corroborated by market data, in such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, as well as calculation of implied volatilities. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The Company regularly evaluates and validates the inputs used to determine fair value of Level 3 contracts by using pricing services to support the underlying market price of the commodity.



128


The Company uses a discounted cash flow valuation technique to fair value its derivative assets and liabilities. The primary inputs in the valuation models for commodity contracts are market observable forward commodity curves and risk-free discount rates and to a lesser degree credit spreads and volatilities. The primary inputs into the valuation of interest rate swaps and foreign currency contracts are forward interest rates and foreign currency exchange rates and to a lesser degree credit spreads.

Recurring Fair Value Measurements

The following table summarizes the financial instruments measured at fair value on a recurring basis classified in the fair value hierarchy (Level 1, 2 or 3) based on the inputs used for valuation in the consolidated balance sheets:
 
As of December 31, 2017
 
As of December 31, 2016
(In thousands)
Level 1
 
Level 2
 
Level 3
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Total
Assets
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest rate swaps
$

 
$
4,686

 
$

 
$
4,686

 
$

 
$
1,561

 
$

 
$
1,561

Commodity contracts

 
27,396

 
80,268

 
107,664

 

 
37,195

 
66,138

 
103,333

Foreign currency contracts

 

 

 

 

 
1,413

 

 
1,413

Total derivative assets
$

 
$
32,082

 
$
80,268

 
$
112,350

 
$

 
$
40,169

 
$
66,138

 
$
106,307

Liabilities
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest rate swaps
$

 
$
7,887

 
$

 
$
7,887

 
$

 
$
32,377

 
$

 
$
32,377

Foreign currency contracts

 
36

 

 
36

 

 

 

 

Total derivative liabilities
$

 
$
7,923

 
$

 
$
7,923

 
$

 
$
32,377

 
$

 
$
32,377


The Company's interest rate swaps, commodity contracts not designated as hedges and foreign currency contracts are considered Level 2, since all significant inputs are corroborated by market observable data. The Company's commodity contracts designated as hedges are considered Level 3 as they contain significant unobservable inputs. There were no transfers in or out of Level 1, Level 2 and Level 3 during the year ended December 31, 2017.

The following table reconciles the changes in the fair value of derivative instruments classified as Level 3 in the fair value hierarchy for the years ended December 31, 2017 and 2016:
 
Year Ended December 31,
(In thousands)
2017
 
2016
Beginning balance
$
66,138

 
$
63,154

Realized and unrealized gains (losses):
 
 
 
Included in other comprehensive income
11,207

 
8,104

Included in operating revenues, net
12,205

 
7,451

Settlements
(9,282
)
 
(12,571
)
Balance as of December 31
$
80,268

 
$
66,138


The significant unobservable inputs used in the valuation of the Company's commodity contracts categorized as Level 3 in the fair value hierarchy as of December 31, 2017 are as follows:
(In thousands, except range)
 
Fair Value as of December 31, 2017
 
 
 
 
 
 
 
 
Transaction Type
 
Assets
 
Liabilities
 
Valuation Technique
 
Unobservable Inputs
 
Range
Commodity contracts - power
 
$
80,268

 
$

 
Discounted cash flow
 
Forward price (per MWh)
 
$
13.8

-
$
77.4

 
 
 
 
 
 
Option model
 
Volatilities
 
3.0
%
-
7.1
%


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The sensitivity of the Company's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows:
Significant Unobservable Input
 
Position
 
Impact on Fair Value Measurement
Increase (decrease) in forward price
 
Forward sale
 
Decrease (increase)
Increase (decrease) in implied volatilities
 
Purchase option
 
Increase (decrease)

The Company measures the sensitivity of the fair value of its Level 3 commodity contracts to potential changes in commodity prices using a mark-to-market analysis based on the current forward commodity prices and estimates of the price volatility. An increase in power forward prices will produce a mark-to-market loss, while a decrease in prices will result in a mark-to-market gain.

Fair Value of Debt

The carrying amount and estimated fair value of the Company's long-term debt as of December 31, 2017 and 2016 is as follows:
 
 
As of December 31, 2017
 
As of December 31, 2016
(In thousands)
 
Carrying Amount
 
Fair Value
 
Carrying Amount
 
Fair Value
Long-term debt, including current portion
 
$
3,598,800

 
$
3,702,470

 
$
3,950,914

 
$
4,080,397


The fair value of the Company's long-term debt, except the senior notes was determined using inputs classified as Level 2 and a discounted cash flow approach using market rates for similar debt instruments. The fair value of the senior notes is based on market price information which is classified as a Level 1 input. They are measured using the last available trades at the end of each respective fiscal year. The fair value of the New Senior Notes due 2023, Senior Notes due 2025 and Senior Notes due 2028 were 99.50%, 109.50% and 99.38% of face value as of December 31, 2017, respectively. The fair value of the Senior Notes due 2023 and Senior Notes due 2025 were 101.38% and 103.75% of face value as of December 31, 2016, respectively.

Nonrecurring Fair Value Measurements

Assets and liabilities that are measured at fair value on a nonrecurring basis relate primarily to renewable energy facilities, goodwill and intangibles, which are remeasured when the derived fair value is below carrying value on the Company's consolidated balance sheet. For these assets, the Company does not periodically adjust carrying value to fair value except in the event of impairment. When the impairment has occurred, the Company measures the impairment and adjusts the carrying value as discussed in Note 2. Summary of Significant Accounting Policies.

During the fourth quarter of 2016, certain long-lived assets met the criteria to be classified as held for sale (as discussed in Note 4. Assets Held for Sale). The fair value of these long-lived assets was measured, resulting in expected disposal losses of $15.7 million. The long-lived asset fair value amount of $19.5 million was measured by obtaining multiple bids from prospective buyers. The Company did not engage third-party appraisers. The fair value measurement was categorized as Level 2, as significant observable inputs were used in the valuation. The expected disposal losses, which represented the difference between the fair value less costs to sell and the carrying amount of the assets and liabilities held for sale, were recognized in impairment of renewable energy facilities within the consolidated statement of operations for the year ended December 31, 2016. As discussed in Note 4. Assets Held for Sale, the Company closed on the sale of these assets in the first half of 2017 and no additional loss was recognized as a result of the sale.

As discussed in Note 8. Goodwill, the Company performed its annual impairment test of the carrying value of its goodwill as of December 1, 2016 and concluded that the goodwill amount of $55.9 million was fully impaired. The inputs used to measure the estimated fair value of goodwill are classified as a Level 3 fair value measurement due to the significance of unobservable inputs using company-specific information.



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15. STOCKHOLDERS' EQUITY

January 2015 Public Offering

On January 22, 2015, TerraForm Power sold 13,800,000 shares of its Class A common stock to the public in a registered offering including 1,800,000 shares sold pursuant to the underwriters' overallotment option. TerraForm Power received net proceeds of $390.6 million, which were used to purchase 13,800,000 Class A units of Terra LLC. Terra LLC used $50.9 million to repurchase 1,800,000 Class B units from SunEdison. Concurrent with this transaction, 1,800,000 shares of TerraForm Power Class B common stock were canceled.

June 2015 Public Offering

On June 24, 2015, TerraForm Power sold 18,112,500 shares of its Class A common stock to the public in a registered offering including 2,362,500 shares sold pursuant to the underwriters' overallotment option. TerraForm Power received net proceeds of $667.6 million, which were used to purchase 18,112,500 Class A units of Terra LLC. Terra LLC used $87.1 million to repurchase 2,362,500 Class B units from SunEdison. Concurrent with this transaction, 2,362,500 shares of TerraForm Power Class B common stock were canceled.

Riverstone Exchange

As of May 28, 2015, all outstanding Class B1 units in Terra LLC and all outstanding shares of Class B1 common stock of TerraForm Power held by R/C US Solar Investment Partnership, L.P. (“Riverstone”) had been converted into Class A units of Terra LLC held by TerraForm Power and shares of Class A common stock of TerraForm Power.
    
Reduction in SunEdison’s Ownership of Class B Shares

On January 22, 2016, TerraForm Power issued 12,161,844 shares of Class A common stock to affiliates of the D.E. Shaw group, Madison Dearborn Capital Partners IV, L.P. and Northwestern University, and Terra LLC issued 12,161,844 Class A units of Terra LLC to TerraForm Power upon conversion of 12,161,844 Class B shares of TerraForm Power common stock and 12,161,844 Class B units of Terra LLC held by SunEdison. After giving effect to the conversion, SunEdison indirectly owned 48,202,310 Class B shares of TerraForm Power and 48,202,310 Class B units of Terra LLC.

Stockholder Protection Rights Agreement

On July 24, 2016, the Company's Board of Directors (the “Board”) adopted a Stockholder Protection Rights Agreement (the “Rights Agreement”) and declared a dividend of one right on each outstanding share of TerraForm Power Class A common stock. The record date to determine which stockholders were entitled to receive the rights was August 4, 2016. The Rights Agreement was adopted in response to the potential sale of a significant equity stake in the Company by SunEdison and the potential accumulation of TerraForm Power Class A shares. The Rights Agreement and the rights expired in accordance with their terms on August 10, 2017, which was the date of the annual shareholders meeting for 2017 of TerraForm Power.

Merger Consummation and SunEdison Settlement Agreement    
    
As discussed in Note 1. Nature of Operations and Basis of Presentation, on October 16, 2017, pursuant to the Merger Agreement, Merger Sub merged with and into TerraForm Power, with TerraForm Power continuing as the surviving corporation in the Merger. Immediately following the consummation of the Merger, there were 148,086,027 Class A shares of TerraForm Power outstanding, which excludes 138,402 Class A shares that were issued and held in treasury to pay applicable employee tax withholdings for RSUs held by employees that vested upon the consummation of the Merger. As a result of the Merger, Orion Holdings holds 51% of TerraForm Power's outstanding Class A shares.

Prior to the consummation of the Merger, SunEdison was the indirect holder of 100% of the shares of Class B common stock of TerraForm Power and held approximately 83.9% of the combined total voting power of the holders of TerraForm Power’s Class A common stock and Class B common stock. As contemplated by the Merger Agreement and in satisfaction of its obligations under the Settlement Agreement, SunEdison exchanged, effective immediately prior to the effective time of the Merger, all of the Class B units of Terra LLC held by it or any of its controlled affiliates for 48,202,310 Class A shares of TerraForm Power. Following completion of this exchange, all of the issued and outstanding shares of Class B common stock of


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TerraForm Power were automatically redeemed and retired. Pursuant to the Settlement Agreement, immediately following this exchange, the Company issued to SunEdison additional Class A shares such that immediately prior to the effective time of the Merger, SunEdison and certain of its affiliates held an aggregate number of Class A shares equal to 36.9% of TerraForm Power’s fully diluted share count (which was subject to proration based on the Merger consideration election results as discussed below). As a result of the Merger closing, TerraForm Power is no longer a controlled affiliate of SunEdison, Inc. and is now a controlled affiliate of Brookfield.

At the effective time of the Merger, each share of Class A common stock of TerraForm Power issued and outstanding immediately prior to the effective time of the Merger, with the exception of certain excluded shares, was converted into the right to, at the holder’s election and subject to proration as described below, either (i) receive $9.52 per Class A Share, in cash, without interest (the “Per Share Cash Consideration”) or (ii) retain one share of Class A common stock, par value $0.01 per share, of the surviving corporation (the “Per Share Stock Consideration,” and, together with the Per Share Cash Consideration, without duplication, the “Per Share Merger Consideration”). Issued and outstanding shares included shares issued in connection with the SunEdison Settlement Agreement as more fully described above and shares underlying outstanding RSUs of the Company under the Company's long-term incentive plan. At the effective time of the Merger, any vesting conditions applicable to any Company RSU outstanding immediately prior to the effective time of the Merger under the Company’s long-term incentive plan were automatically and without any required action on the part of the holder, deemed to be satisfied in full, and such Company RSU was canceled and converted into the right to receive the Per Share Merger Consideration, including the election of the Per Share Stock Consideration or the Per Share Cash Consideration in respect of each share (in the case of RSUs subject to performance conditions, with such conditions deemed satisfied at “target” levels), less any tax withholdings. The Per Share Stock Consideration was subject to proration in the event that the aggregate number of Class A Shares for which an election to receive the Per Share Stock Consideration exceeded 49% of the TerraForm Power fully diluted share count (the “Maximum Stock Consideration Shares”). Additionally, the Per Share Cash Consideration was subject to proration in the event that the aggregate number of Class A shares for which an election to receive the Per Share Cash Consideration exceeded the TerraForm Power fully diluted share count minus (i) the Maximum Stock Consideration Shares, (ii) any Class A shares currently held by affiliates of Brookfield, and (iii) any shares for which the holders seek appraisal under Delaware law. Based on the results of the consideration election, the elections of the Per Share Stock Consideration were oversubscribed and the proration ratio was 62.6%, which meant that stockholders electing to receive 100% of their merger consideration in stock retained 62.6% of their Class A shares in the Merger and received cash consideration in respect of 37.4% of their shares.

On October 16, 2017, in connection with the consummation of the Merger, the Company entered into a registration rights agreement (the “SunEdison Registration Rights Agreement”) with SunEdison, Inc., SunEdison Holdings Corporation (“SHC”) and SUNE ML 1, LLC (“SML1”). The SunEdison Registration Rights Agreement governed the rights of SunEdison, Inc., SHC, SML1 and certain permitted assigns with respect to the registration for resale of Class A shares held by them immediately following the Merger. The Company registered these shares in December of 2017, and these shares were distributed by SunEdison, Inc., SHC and SML1 under the plan of reorganization in connection with SunEdison's emergence from bankruptcy in December of 2017. 

Upon the consummation of the Merger, the Company's certificate of incorporation was amended and restated. TerraForm Power now has 100,000,000 authorized shares of preferred stock, par value $0.01 per share, and 1,200,000,000 authorized shares of Class A common stock, par value $0.01 per share. There are no other authorized classes of shares, and the Company does not have any issued shares of preferred stock.



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Dividends

The following table presents cash dividends declared and/or paid on Class A common stock during 2017, 2016 and 2015. Prior to the Special Dividend (as defined below), TerraForm Power had not declared or paid a dividend since the quarterly dividend for the third quarter of 2015.
 
Dividends per Share
 
Declaration Date
 
Record Date
 
Payment Date
2017:
 
 
 
 
 
 
 
Special Dividend1
$
1.940

 
October 6, 2017
 
October 16, 2017
 
October 17, 2017
2015:
 
 
 
 
 
 
 
Third Quarter
0.350

 
November 9, 2015
 
December 1, 2015
 
December 15, 2015
Second Quarter
0.335

 
August 6, 2015
 
September 1, 2015
 
September 15, 2015
First Quarter
0.325

 
May 7, 2015
 
June 1, 2015
 
June 15, 2015
2014:
 
 
 
 
 
 
 
Fourth Quarter
0.270

 
December 22, 2014
 
March 2, 2015
 
March 16, 2015
———
(1)
On October 6, 2017, the Board declared the payment of a special cash dividend (the “Special Dividend”) to holders of record immediately prior to the effective time of the Merger in the amount of $1.94 per fully diluted share, which included the Company’s issued and outstanding Class A shares, Class A shares issued to SunEdison pursuant to the Settlement Agreement (more fully described above) and Class A shares underlying outstanding RSUs of the Company under the Company’s long-term incentive plan.

On February 6, 2018, the Board declared a quarterly dividend with respect to TerraForm Power's Class A common stock of $0.19 per share. The dividend is payable on March 30, 2018 to shareholders of record as of February 28, 2018. This dividend represents the Company's first dividend payment under Brookfield sponsorship.

16. STOCK-BASED COMPENSATION

The Company has an equity incentive plan that provides for the award of incentive and nonqualified stock options, restricted stock awards (“RSAs”) and RSUs to personnel and directors who provide services to the Company, including personnel and directors who also provide services to the Company's affiliates, including SunEdison and TerraForm Global, Inc. during the periods those companies were affiliates of the Company. The maximum contractual term of an award is ten years from the date of grant. As of December 31, 2017, an aggregate of 3,926,121 shares of Class A common stock were available for issuance under this plan. Upon exercise of stock options or the vesting of RSUs, the Company will issue shares that have been previously authorized to be issued.

Historically, stock-based compensation costs related to equity awards in the Company's stock were allocated to the Company, SunEdison and TerraForm Global, Inc. based on the relative percentage of time that the personnel and directors spent providing services to the respective companies. As of January 1, 2017, the Company hired certain former employees of SunEdison who provided dedicated services to the Company. The amount of stock-based compensation expense related to equity awards in the Company's stock which has been awarded to the Company’s employees was $11.3 million, $3.4 million and $12.1 million for the years ended December 31, 2017, 2016 and 2015, respectively, and is reflected in the consolidated statements of operations within general and administrative expenses. The total amount of stock-based compensation cost related to equity awards in the Company's stock which has been allocated to SunEdison and TerraForm Global, Inc. was $3.4 million for the years ended December 31, 2017 and 2016 and $10.5 million for the year ended December 31, 2015, and was recognized as a distribution to SunEdison within Net SunEdison investment on the consolidated statement of stockholders' equity with no impact to the Company's consolidated statement of operations. Similarly, stock-based compensation costs related to equity awards in the stock of SunEdison, Inc. and TerraForm Global, Inc. awarded to employees of the Company were allocated to the Company. The amount of stock-based compensation expense related to equity awards in the stock of SunEdison, Inc. and TerraForm Global, Inc. that was allocated to the Company was $5.5 million, $2.7 million and $1.0 million for the years ended December 31, 2017, 2016 and 2015, respectively, and is reflected in the consolidated statement of operations within general and administrative expenses - affiliate and has been treated as an equity contribution from SunEdison within Net SunEdison investment on the consolidated statements of stockholders' equity. In July of 2017, the Bankruptcy Court approved SunEdison's plan of reorganization which provided that all unvested equity awards in the stock of SunEdison, Inc. would be canceled. As a result, all previously unrecognized compensation cost pertaining to unvested equity awards in the stock of SunEdison, Inc. that


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were held by the Company's employees of $2.2 million was allocated to the Company, which is reflected within the stock-based compensation expense amount for the year ended December 31, 2017.

Restricted Stock Awards

RSAs provide the holder with immediate voting rights, but are restricted in all other respects until vested. Upon a termination of employment for any reason, any unvested shares of Class A common stock held by the terminated participant will be forfeited. All unvested RSAs are paid dividends and distributions. There were no unvested RSAs as of December 31, 2017.

The following table presents information regarding outstanding RSAs as of December 31, 2017 and changes during the year then ended:
 
 
Number of RSAs Outstanding
 
Weighted-Average Grant-Date Fair Value Per Share
 
Aggregate Intrinsic Value (in millions)
Balance at January 1, 2017
 
366,195

 
$
8.51

 
 
Vested
 
(366,195
)
 
8.51

 
 
Balance as of December 31, 2017
 

 
$

 
$


The total fair value of RSAs that vested during the years ended December 31, 2017, 2016 and 2015 was $4.3 million, $5.8 million and $65.0 million, respectively. No RSAs were granted during those periods. As of December 31, 2017, there was no unrecognized compensation cost in relation to RSAs.

The removal of a former Chief Executive Officer of the Company on November 20, 2015 resulted in the forfeiture from an accounting perspective of 454,586 RSAs as well as the immediate accelerated vesting of an additional 454,586 RSAs. The aforementioned termination resulted in a net increase to the Company's stock-based compensation expense for the year ended December 31, 2015 of $0.3 million.

Restricted Stock Units

RSUs will not entitle the holders to voting rights and holders of the RSUs will not have any right to receive dividends or distributions. The following table presents information regarding outstanding RSUs as of December 31, 2017 and changes during the year then ended:
 
 
Number of RSUs Outstanding
 
Aggregate Intrinsic Value (in millions)
 
Weighted Average Remaining
Contractual Life (In Years)
Balance at January 1, 2017
 
1,622,953

 
 
 
 
Granted
 
523,877

 
 
 
 
Vested
 
(1,414,857
)
 
 
 
 
Forfeited
 
(731,973
)
 
 
 
 
Balance as of December 31, 2017
 

 
$

 


The total fair value of RSUs that vested during the years ended December 31, 2017, 2016 and 2015 was $16.7 million, $5.6 million and $5.7 million, respectively. The weighted average fair value of RSUs on the date of grant during the same periods was $12.22, $11.61 and $20.60, respectively.

As discussed in Note 1. Nature of Operations and Basis of Presentation, on October 16, 2017, TerraForm Power consummated the Merger with certain affiliates of Brookfield. Pursuant to the TerraForm Power 2014 Second Amended and Restated Long-Term Incentive Plan, the Merger resulted in a change of control causing all unvested equity awards issued under the plan to vest. As a result, the Company recognized a $7.0 million stock-based compensation charge in the fourth quarter of 2017, which is reflected in the consolidated statements of operations within general and administrative expenses. The Company also recognized a $1.0 million charge related to allocated stock-based compensation costs for equity awards in the stock of TerraForm Global, Inc. that vested upon the change of control of TerraForm Power. The charge is reflected in the consolidated


134


statements of operations within general and administrative expenses - affiliate. As of December 31, 2017, the Company had not awarded any additional RSUs, and as a result, there was no unrecognized compensation cost in relation to RSUs as of December 31, 2017.

Time-based RSUs

During the years ended December 31, 2017, 2016 and 2015, the Company awarded 523,877, 439,595 and 1,979,098 time-based RSUs, respectively, to certain employees and executive officers of SunEdison, TerraForm Global, Inc. and the Company. The weighted average grant-date fair value of these time-based awards during the same periods was $6.4 million, $5.1 million and $29.4 million, respectively, which was calculated based on the Company's closing stock price on the respective dates of grant. The vesting schedules of the awarded RSUs ranged from six months to four years, and the Company was recognizing the grant-date fair value as compensation cost on a straight-line basis over the vesting period.

The removal of a former Chief Financial Officer of the Company on November 20, 2015 resulted in the forfeiture of 106,250 RSUs as well as the immediate accelerated vesting of an additional 106,250 RSUs. The aforementioned termination resulted in a net increase to the Company's stock-based compensation expense for the year ended December 31, 2015 of $0.9 million.
Performance-based RSUs

On July 28, 2015, SunEdison began recognizing expense related to 199,239 performance-based RSUs granted by the Company to certain employees of First Wind in connection with its acquisition by SunEdison on January 29, 2015. The performance-based awards were issued in three tranches covering the 2015, 2016 and 2017 fiscal year performance periods and were based on the achievement of targets related to additions to SunEdison's renewable energy generation project development pipeline and backlog, the volume of renewable energy generation projects transferred into the Company or SunEdison's warehouse vehicles and the achievement of cash available for distribution by wind power plants sold to the Company through the First Wind Acquisition agreement. The grant-date fair value of these awards was $6.2 million which was being recognized as compensation expense on a straight-line basis over the requisite service periods of one year for the 2015 tranche, two years for the 2016 tranche, and three years for the 2017 tranche. The grant-date fair value of these awards was calculated based on the Company's stock price on the date of grant since meeting the requisite performance conditions was considered probable as of that date. As the achievement of these performance metrics was not considered probable as of the first quarter of 2016, all previously recognized compensation expense for the tranches covering 2015 and 2016 was reversed during the first quarter of 2016. These performance-based RSUs were all forfeited prior to the consummation of the Merger.

Stock Options

As of December 31, 2017 and 2016, there were no outstanding stock options and no unrecognized compensation cost in relation to stock options.

17. LOSS PER SHARE
    
Basic loss per share is computed by dividing net loss attributable to Class A common stockholders by the number of weighted average ordinary shares outstanding during the period. Diluted loss per share is computed by adjusting basic loss per share for the impact of weighted average dilutive common equivalent shares outstanding during the period, unless the impact is anti-dilutive. Common equivalent shares represent the incremental shares issuable for unvested restricted Class A common stock.

Unvested RSAs that contain non-forfeitable rights to dividends are treated as participating securities and are included in the loss per share computation using the two-class method. The two-class method is an earnings allocation formula that treats participating securities as having rights to earnings that would otherwise have been available to common stockholders. This method determines earnings (loss) per share based on dividends declared on common stock and participating securities (i.e. distributed earnings), as well as participation rights of participating securities in any undistributed earnings. Undistributed losses are not allocated to participating securities since they are not contractually obligated to share in the losses of the Company. The numerator for undistributed loss per share is also adjusted by the amount of deemed dividends related to the accretion of redeemable non-controlling interest since the redemption value of the non-controlling interest was considered to be at an amount other than fair value (and was considered a right to an economic distribution that differed from other common stockholders) and as accretion adjustments were recognized in additional paid-in capital and not within net loss attributable to


135


Class A common stockholders.
    
Basic and diluted loss per share of the Company's Class A common stock for the years ended December 31, 2017, 2016 and 2015 was calculated as follows:
 
 
Year Ended December 31,
(In thousands, except per share amounts)
 
2017
 
2016
 
2015
Basic and diluted loss per share:
 
 
 
 
 
 
Net loss attributable to Class A common stockholders
 
$
(164,189
)
 
$
(129,847
)
 
$
(79,886
)
Less: accretion of redeemable non-controlling interest
 
(6,729
)
 
(3,962
)
 

Less: dividends paid on Class A shares and participating RSAs
 
(285,497
)
 

 
(74,377
)
Undistributed loss attributable to Class A shares
 
$
(456,415
)
 
$
(133,809
)
 
$
(154,263
)
 
 
 
 
 
 
 
Weighted average basic and diluted Class A shares outstanding1
 
103,866

 
90,815

 
65,883

 
 
 
 
 
 
 
Distributed earnings per share
 
$
2.75

 
$

 
$
1.09

Undistributed loss per share
 
(4.40
)
 
(1.47
)
 
(2.34
)
Basic and diluted loss per share
 
$
(1.65
)
 
$
(1.47
)
 
$
(1.25
)
———
(1)
The computation for diluted loss per share of the Company's Class A common stock for the year ended December 31, 2017 excludes the impact of potentially dilutive unvested RSAs and RSUs outstanding during the year as the effect would have been anti-dilutive. As of December 31, 2017, there were no potentially dilutive unvested securities. The computation for diluted loss per share of the Company's Class A common stock for the year ended December 31, 2016 excludes 459,800 of potentially dilutive unvested RSAs and 1,622,953 of potentially dilutive unvested RSUs because the effect would have been anti-dilutive, and the computation for diluted loss per share of the Company's Class A common stock for the year ended December 31, 2015 excludes 1,334,158 of potentially dilutive unvested RSAs, 3,208,394 of potentially dilutive unvested RSUs and 56,250 of potentially dilutive vested and exercisable options to purchase the Company's shares because the effect would have been anti-dilutive.



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18. NON-CONTROLLING INTERESTS

Non-controlling Interests

Non-controlling interests represent the portion of net assets in consolidated entities that are not owned by the Company. The following table presents the non-controlling interest balances reported in stockholders’ equity in the consolidated balance sheets as of December 31, 2017 and 2016:
 
 
As of December 31,
(In thousands)
 
2017
 
2016
SunEdison's non-controlling interest in Terra LLC1
 
$

 
$
660,799

Non-controlling interests in renewable energy facilities2
 
859,999

 
804,243

Total non-controlling interests
 
$
859,999

 
$
1,465,042

————
(1)
As of December 31, 2016, TerraForm Power owned 65.7% of Terra LLC and consolidated the results of Terra LLC through its controlling interest, with SunEdison's 34.3% interest shown as a non-controlling interest. As discussed in Note 1. Nature of Operations and Basis of Presentation, on October 16, 2017, SunEdison exchanged all of its Class B units in Terra LLC for Class A shares of TerraForm Power, and after giving effect to this exchange, TerraForm Power owned 100% of Terra LLC. In accordance with ASC 810-10-45-23, the Company reallocated SunEdison's non-controlling interest balance as of such date of $641.5 million to additional paid-in capital (which was net of the reallocation of $0.6 million of previously allocated accumulated other comprehensive losses back to accumulated other comprehensive income).
(2)
As discussed in Note 5. Acquisitions and below, as part of the Settlement Agreement, the Option Agreement between Terra LLC and Sun Edison LLC with respect to Invenergy Wind's remaining 9.9% interest in certain subsidiaries of the Company was rejected upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017. As a result, the Company is no longer obligated to perform on its Option Agreement, and as of October 16, 2017, the Invenergy Wind non-controlling interest amount of $131.8 million was no longer considered redeemable and was reclassified to non-controlling interests as of such date. In addition, as a result of the Company's sale of TerraForm Resi Solar Manager, LLC, a subsidiary of the Company that owned and operated 8.9 MW of residential rooftop solar installations, during the second quarter of 2017 (see Note 4. Assets Held for Sale), the amount of non-controlling interest in this entity of $8.7 million was deconsolidated.

Non-controlling Interest Buyout

On March 31, 2015, the Company completed the buyout of approximately 92% of one of the partners' tax equity ownership interest in the Company's Kaheawa Wind Power I facility. The value associated with the buyout was deemed to be the fair value of the non-controlling interest as of the acquisition date. The cash paid for this buyout was $54.7 million.

Redeemable Non-controlling Interests

Non-controlling interests in subsidiaries that are redeemable either at the option of the holder or at fixed and determinable prices at certain dates are classified as redeemable non-controlling interests in subsidiaries between liabilities and stockholders' equity in the consolidated balance sheets. The redeemable non-controlling interests in subsidiaries balance is determined using the hypothetical liquidation at book value method for the VIE funds or allocation of share of income or losses in other subsidiaries subsequent to initial recognition; however, the non-controlling interests balance cannot be less than the estimated redemption value.

The Company recorded a $6.7 million and $4.0 million adjustment during the years ended December 31, 2017 and 2016, respectively, to the value of the Invenergy Wind redeemable non-controlling interest, reflecting the excess of the future redemption value over its carrying amount based on SEC guidance in ASC 480-10-S99-3A. There was no similar adjustment recorded for the year ended December 31, 2015. As discussed in Note 5. Acquisitions, the Company was accreting the redemption value of the Invenergy Wind redeemable non-controlling interest over the redemption period using the straight-line method and accretion adjustments were recorded against additional paid-in capital. As part of the Settlement Agreement, the Option Agreement between Terra LLC and Sun Edison LLC with respect to Invenergy Wind's remaining 9.9% interest in certain subsidiaries of the Company was rejected upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017. As a result, the Company is no longer obligated to perform on its Option Agreement, and as of October 16, 2017, the Invenergy Wind non-controlling interest amount of $131.8 million was no longer considered redeemable and was reclassified to non-controlling interests as of such date. The redemption adjustments recorded in additional paid-in capital will remain in additional paid-in capital.


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The following table presents the activity of the redeemable non-controlling interests balance for the years ended December 31, 2017, 2016 and 2015:
 
 
Redeemable Non-controlling Interests
(In thousands)
 
Capital
 
Retained Earnings
 
Total
Balance as of December 31, 2014
 
$
24,338

 
$

 
$
24,338

Consolidation of redeemable non-controlling interests in acquired renewable energy facilities
 
151,408

 

 
151,408

Sale of membership interests and contributions
 
3,032

 

 
3,032

Repurchase of redeemable non-controlling interest in renewable energy facility
 
(8,504
)
 

 
(8,504
)
Distributions
 
(2,764
)
 

 
(2,764
)
Currency translation adjustment
 
(311
)
 

 
(311
)
Net income
 

 
8,512

 
8,512

Balance as of December 31, 2015
 
$
167,199

 
$
8,512

 
$
175,711

Sale of membership interests and contributions
 
1,011

 

 
1,011

Distributions
 
(10,764
)
 

 
(10,764
)
Acquisition accounting adjustment
 
(7,918
)
 

 
(7,918
)
Accretion
 
3,962

 

 
3,962

Net income
 

 
18,365

 
18,365

Balance as of December 31, 2016
 
$
153,490

 
$
26,877

 
$
180,367

Distributions
 
(7,818
)
 

 
(7,818
)
Accretion
 
6,729

 

 
6,729

Net income
 

 
10,884

 
10,884

Reclassification of Invenergy Wind Interest to non-controlling interests
 
(130,241
)
 
(1,581
)
 
(131,822
)
Balance as of December 31, 2017
 
$
22,160


$
36,180


$
58,340


19. COMMITMENTS AND CONTINGENCIES

Letters of Credit

The Company's customers, vendors and regulatory agencies often require the Company to post letters of credit in order to guarantee performance under relevant contracts and agreements. The Company is also required to post letters of credit to secure obligations under various swap agreements and leases and may, from time to time, decide to post letters of credit in lieu of cash deposits in reserve accounts under certain financing arrangements. The amount that can be drawn under some of these letters of credit may be increased from time to time subject to the satisfaction of certain conditions. As of December 31, 2017, the Company had outstanding letters of credit under the New Revolver of $102.6 million and outstanding project-level letters of credit of $147.0 million.

Guarantee Agreements

The Company and its subsidiaries have provided guarantees to certain of its institutional tax equity investors and financing parties in connection with its tax equity financing transactions. These guarantees do not guarantee the returns targeted by the tax equity investors or financing parties, but rather support any potential indemnity payments payable under the tax equity agreements, including related to management of tax partnerships and recapture of tax credits or renewable energy grants in connection with transfers of the Company’s direct or indirect ownership interests in the tax partnerships to entities that are not qualified to receive those tax benefits. The Company and its subsidiaries have also provided guarantees in connection with acquisitions of third party assets or to support project contractual obligations, including renewable energy credit sales agreements. The Company and its subsidiaries have also provided other capped or limited contingent guarantees and other support obligations with respect to certain project-level indebtedness.


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Commitments to Acquire Renewable Energy Facilities

As of December 31, 2017, the Company did not have any open commitments to acquire renewable energy facilities.

Operating Leases

The Company leases land and buildings under operating leases. Total rental expense was $21.0 million, $23.5 million and $12.2 million during the years ended December 31, 2017, 2016 and 2015, respectively. The following table summarizes the Company's future commitments under operating leases as of December 31, 2017:
(In thousands)
 
2018
 
2019
 
2020
 
2021
 
2022
 
Thereafter
 
Total
Rent
 
$
14,940

 
$
14,545

 
$
14,713

 
$
14,922

 
$
15,062

 
$
248,175

 
$
322,357


Legal Proceedings
    
The Company is not a party to any material legal proceedings other than various administrative and regulatory proceedings arising in the ordinary course of the Company's business or as described below. While the Company cannot predict with certainty the ultimate resolution of such proceedings or other claims asserted against the Company, certain of the claims, if adversely concluded, could result in substantial damages or other relief.

Securities Class Action

On April 4, 2016, a securities class action under federal securities laws (Chamblee v. TerraForm Power, Inc., et al., Case No. 1:16-cv-00981-JFM) (the "Chamblee Class Action") was filed in the United States District Court for the District of Maryland against the Company and two of its former officers (one of which was also a director of the Company) asserting claims under Section 10(b) and 20(a) of the Securities and Exchange Act of 1934 and SEC Rule 10b-5 on behalf of a putative class. The complaint alleges that the defendants made materially false and misleading statements regarding the Company’s business, operational and compliance policies, including with respect to disclosures regarding SunEdison’s internal controls and the Company's reliance on SunEdison. An amended complaint was filed on September 26, 2016 and a former officer and director of the Company were added as defendants. On October 4, 2016, the Judicial Panel on Multidistrict Litigation transferred this matter to the U.S. District Court for the Southern District of New York (SDNY) for consolidated or coordinated pretrial proceedings. On December 19, 2016, an initial case management conference was held in the multidistrict litigation proceedings in the SDNY. The Court entered an order requiring all parties to the multidistrict litigation to mediate and entered a partial stay of all proceedings through March 31, 2017. On March 24, 2017, the plaintiffs filed an amended complaint adding three additional directors and officers of the Company as defendants, as well as additional factual allegations. On June 9, 2017, the Company filed a motion to dismiss the case. After mediation, the parties agreed in principle to a settlement of $14.8 million on behalf of a putative settlement class containing all persons and entities that purchased or otherwise acquired the publicly traded securities of the Company between July 18, 2014 and March 15, 2016, expressly conditioned on, among other things, funding of the settlement by the Company’s directors’ and officers’ liability insurance providers in the amount of $13.63 million. The Company reserved $1.13 million for its estimated probable loss related to this complaint as of December 31, 2016, which was the amount the Company would have been prepared to fund the settlement out of its own funds. On September 14, 2017, the U.S. District Court for the SDNY preliminarily approved the settlement and provided the Company with an express termination right in the event that the settlement was not timely funded with proceeds from the directors’ and officers’ liability insurance. In January of 2018, the insurers funded $13.63 million and the Company funded $1.13 million into the settlement escrow account. The settlement was finally approved at a hearing of the court on January 31, 2018. As of December 31, 2017, the Company recorded an insurance receivable of $13.63 million within prepaid expenses and other current assets and a corresponding additional liability of $13.63 million within accounts payable, accrued expenses and other current liabilities in the consolidated balance sheet.

Pursuant to the Merger Agreement with Orion Holdings, the Company has agreed to issue additional shares of Class A common stock to Orion Holdings for no additional consideration in respect of the Company’s net losses, such as out-of-pocket losses, damages, costs, fees and expenses, within a prescribed period following the final resolution of the Chamblee Class Action. These net losses would include the $1.13 million contributed by the Company to the settlement but would not include the $13.63 million contributed by the Company's insurers and certain attorneys’ fees that TerraForm Global, Inc. has agreed to


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reimburse to the Company pursuant to the insurance allocation arrangements described in Insurance Allocation Agreements within Note 20. Related Parties.

Settlement Agreement with Latin America Power Holding

On April 20, 2016, TerraForm Power and Terra LLC (together, the “TerraForm Power Parties”) entered into a Settlement and Mutual Release Agreement (the “LAP Settlement Agreement”) with BTG Pactual Brazil Infrastructure Fund II, L.P., P2 Brasil Private Infrastructure Fund II, L.P., P2 Fund II LAP Co-Invest, L.P., P2 II LAP Co-Invest UK, L.P., GMR Holding B.V. (collectively, the “LAP Shareholders”), and Roberto Sahade, LAP’s chief executive officer (together with the LAP Shareholders and the TerraForm Power Parties, the “Parties”). The LAP Settlement Agreement resolved the disputes between the Parties in connection with the previously announced termination of that certain Amended and Restated Share Purchase Agreement, dated May 19, 2015 (the “Share Purchase Agreement”), among SunEdison Holdings Corporation and the LAP Shareholders, and the guarantee issued by TerraForm Power in connection therewith, relating to the acquisition of Latin America Power Holding, B.V. (“LAP”), that were the subject of an arbitration proceeding (the “Arbitration”). Pursuant to the LAP Settlement Agreement, TerraForm Power made a one-time payment to LAP in the amount of $10.0 million in April of 2016 in exchange for and contingent on the termination of the Arbitration against TerraForm Power. This amount was accrued for in 2015 and is reported in general and administrative expenses in the consolidated statement of operations for the year ended December 31, 2015. None of the Parties admitted to any wrongdoing or liability with respect to the claims asserted in the Arbitration, and the Parties granted each other full releases of any further obligations under the Share Purchase Agreement and related agreements (including the TerraForm Power guarantee).
    
Claim relating to First Wind Acquisition

On May 27, 2016, D.E. Shaw Composite Holdings, L.L.C. and Madison Dearborn Capital Partners IV, L.P., as the representatives of the sellers (the “First Wind Sellers”) filed an amended complaint for declaratory judgment against TerraForm Power and Terra LLC in the Supreme Court of the State of New York alleging breach of contract with respect to the Purchase and Sale Agreement, dated as of November 17, 2014 (the “FW Purchase Agreement”) between, among others, SunEdison, TerraForm Power and Terra LLC and the First Wind Sellers. The amended complaint alleges that Terra LLC and SunEdison became jointly obligated to make $231.0 million in earn-out payments in respect of certain development assets SunEdison acquired from the First Wind Sellers under the FW Purchase Agreement, when those payments were purportedly accelerated by SunEdison's bankruptcy and by the resignations of two SunEdison employees. The amended complaint further alleges that TerraForm Power, as guarantor of certain Terra LLC obligations under the FW Purchase Agreement, is liable for this sum. The defendants filed a motion to dismiss the amended complaint on July 5, 2016, on the ground that, among other things, SunEdison is a necessary party to this action. The plaintiffs filed an opposition to the motion to dismiss on August 22, 2016. The defendants filed their reply on September 12, 2016. A hearing on the motion to dismiss took place on January 24, 2017. On February 6, 2018, the court denied the Company’s motion to dismiss, and the Company expects discovery to proceed in the case. The Company cannot predict the impact on this litigation of any information that may become available in discovery.

The Company has agreed to issue additional shares of Class A common stock to Orion Holdings for no additional consideration in respect of the Company’s net losses, such as out-of-pocket losses, damages, costs, fees and expenses, upon the final resolution of the litigation brought by the First Wind Sellers described above. The number of additional shares of Class A common stock to be issued to Orion Holdings is subject to a pre-determined formula as set forth in the Merger Agreement as described in greater detail in the Company’s Definitive Proxy Statement filed on Schedule 14A with the SEC on September 6, 2017. As of the date hereof, the Company is unable to predict the quantum of any net losses arising from the litigation brought by the First Wind Sellers described above or the number of additional shares, if any, that may be required to be issued to Orion Holdings pursuant to the terms of the Merger Agreement in connection with any such final resolution.

The issuance of additional shares to Orion Holdings would dilute the holdings of the Company's common stockholders and may negatively affect the value of the Company's common stock.

The Company believes the First Wind Sellers’ allegation is without merit and will contest the claim and allegations vigorously. However, the Company cannot predict with certainty the ultimate resolution of any proceedings brought in connection with such a claim.



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Whistleblower Complaint By Francisco Perez Gundin

On May 18, 2016, the Company’s former Director and Chief Operating Officer, Francisco Perez Gundin (“Perez”), filed a complaint against the Company, TerraForm Global, Inc. and certain individuals, with the United States Department of Labor. The complaint alleges that the defendants engaged in a retaliatory termination of Mr. Perez's employment after he allegedly voiced concerns to SunEdison’s Board of Directors about public representations made by SunEdison officers regarding SunEdison’s liquidity position, and after he allegedly voiced his opposition to transactions that he alleges were self-interested and which he alleges SunEdison forced on the Company. He alleges that the Company participated in SunEdison’s retaliatory termination by constructively terminating his position as Chief Operating Officer of the Company in connection with SunEdison’s constructive termination of his employment. He seeks lost wages, bonuses, benefits, and other money that he alleges that he would have received if he had not been subjected to the allegedly retaliatory termination. The Company's Position Statement in response to the complaint was filed in October of 2016.

On February 21, 2017, Mr. Perez filed Gundin v. TerraForm Global, Inc. et al. against TerraForm Power, TerraForm Global, Inc. and certain individuals as defendants in the United States District Court for the District of Maryland. The complaint asserts claims for retaliation, breach of the implied covenant of good faith and fair dealing and promissory estoppel based on the same allegation in Mr. Perez's Department of Labor complaint. On March 15, 2017, the Company filed notice with the Judicial Panel on Multidistrict Litigation to transfer this action to the Southern District of New York where the Chamblee Class Action was tried and other cases not involving the Company relating to the SunEdison Bankruptcy are being tried. The plaintiff did not oppose the transfer, which was approved by the Judicial Panel on Multidistrict Litigation. On November 6, 2017, TerraForm Power and the other defendants filed a motion to dismiss Mr. Perez's complaint, and Mr. Perez filed a response on December 21, 2017.

The Company has agreed to issue additional shares of Class A common stock to Orion Holdings for no additional consideration in respect of the Company’s net losses, such as out-of-pocket losses, damages, costs, fees and expenses, upon the final resolution of the litigation brought by Mr. Perez described above. The number of additional shares of Class A common stock to be issued to Orion Holdings is subject to a pre-determined formula as set forth in the Merger Agreement as described in greater detail in the Company’s Definitive Proxy Statement filed on Schedule 14A with the SEC on September 6, 2017. As of the date hereof, the Company is unable to predict the quantum of any net losses arising from the litigation brought by Mr. Perez described above or the number of additional shares, if any, that may be required to be issued to Orion Holdings pursuant to the terms of the Merger Agreement in connection with any such final resolution.

The issuance of additional shares to Orion Holdings would dilute the holdings of the Company's common stockholders and may negatively affect the value of the Company's common stock.

The Company reserved for its estimated loss related to this complaint in 2016, which was not considered material to the Company's consolidated results of operations, and this amount remains accrued as of December 31, 2017. However, the Company is unable to predict with certainty the ultimate resolution of these proceedings.

Whistleblower Complaint By Carlos Domenech Zornoza

On May 10, 2016, the Company’s former Director and Chief Executive Officer, Carlos Domenech Zornoza (“Domenech”), filed a complaint against the Company, TerraForm Global, Inc. and certain individuals, with the United States Department of Labor. The complaint alleges that the defendants engaged in a retaliatory termination of Mr. Domenech’s employment on November 20, 2015 after he allegedly voiced concerns to SunEdison’s Board of Directors about public representations made by SunEdison officers regarding SunEdison’s liquidity position, and after he allegedly voiced his opposition to transactions that he alleges were self-interested and which he alleges SunEdison forced on the Company. He alleges that the Company participated in SunEdison’s retaliatory termination by terminating his position as Chief Executive Officer of the Company in connection with SunEdison’s termination of his employment. He seeks lost wages, bonuses, benefits, and other money that he alleges that he would have received if he had not been subjected to the allegedly retaliatory termination. The Company's Position Statement in response to the complaint was filed in October of 2016.

On February 21, 2017, Mr. Domenech filed Domenech Zornoza v. TerraForm Global, Inc. et. al against TerraForm Power, TerraForm Global, Inc. and certain individuals as defendants in the United States District Court for the District of Maryland. The complaint asserts claims for retaliation, breach of the implied covenant of good faith and fair dealing and promissory estoppel based on the same allegations in Mr. Domenech's Department of Labor complaint. On March 15, 2017, the


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Company filed notice with the Judicial Panel on Multidistrict Litigation to transfer this action to the Southern District of New York where the Chamblee Class Action was tried and other cases not involving the Company relating to the SunEdison Bankruptcy are being tried. The plaintiff opposed the transfer. However, the transfer was approved by the Judicial Panel on Multidistrict Litigation. On November 6, 2017, TerraForm Power and the other defendants filed a motion to dismiss Mr. Domenech's complaint, and Mr. Domenech filed a response on December 21, 2017.

The Company has agreed to issue additional shares of Class A common stock to Orion Holdings for no additional consideration in respect of the Company’s net losses, such as out-of-pocket losses, damages, costs, fees and expenses, upon the final resolution of the litigation brought by Mr. Domenech described above. The number of additional shares of Class A common stock to be issued to Orion Holdings is subject to a pre-determined formula as set forth in the Merger Agreement as described in greater detail in the Company’s Definitive Proxy Statement filed on Schedule 14A with the SEC on September 6, 2017. As of the date hereof, the Company is unable to predict the quantum of any net losses arising from the litigation brought by Mr. Domenech described above or the number of additional shares, if any, that may be required to be issued to Orion Holdings pursuant to the terms of the Merger Agreement in connection with any such final resolution.
    
The issuance of additional shares to Orion Holdings would dilute the holdings of the Company's common stockholders and may negatively affect the value of the Company's common stock.

The Company reserved for its estimated loss related to this complaint in 2016, which was not considered material to the Company's consolidated results of operations, and this amount remains accrued as of December 31, 2017. However, the Company is unable to predict with certainty the ultimate resolution of these proceedings.

Eastern Maine Electric Cooperative Litigation

On November 21, 2016, the Penobscot County Maine Superior Court entered judgment in the amount of $13.6 million against First Wind Holdings, LLC (“First Wind”), an indirect subsidiary of SunEdison, Inc., and several subsidiaries of the Company. The plaintiff filed judgment liens against the defendants which will stay outstanding through the appeals process. The action involved a claimed breach of contract arising out of a contract between First Wind and Eastern Maine Electric Cooperative, Inc. (“EMEC”), under which First Wind, on behalf of itself and its then wholly-owned subsidiaries, agreed to negotiate a definitive agreement to transfer to EMEC a portion of a transmission line. The transmission line is owned, in part, by one of the Company's subsidiaries, and is the sole means of transmitting power from the Rollins, Stetson I and Stetson II wind farms. The subsidiaries that own these wind farms and the transmission line were acquired by the Company as part of the Company's acquisition of certain of the operating assets of First Wind Holdings. The subsidiaries of the Company settled this matter in the fourth quarter of 2017 for $9.75 million in exchange for a full release of these claims. The amount of the initial judgment was reserved for in 2015 and is reported in general and administrative expenses in the consolidated statement of operations for the year ended December 31, 2015. As a result of this settlement, the Company recorded a $4 million gain within general and administrative expenses for the year ended December 31, 2017.

Threatened Avoidance Actions

On November 7, 2016, the unsecured creditors’ committee in the SunEdison Bankruptcy filed a motion with the Bankruptcy Court seeking standing to assert against the Company, on behalf of SunEdison, avoidance claims arising from payments and other intercompany transactions between the Company and SunEdison dating back to the Company’s initial public offering and including drop-down transactions involving the sale of renewable energy facilities by SunEdison to the Company. The Company’s objection to the standing motion was filed on November 29, 2016. As described in Note 1. Nature of Operations and Basis of Presentation and Note 20. Related Parties, the Company and SunEdison entered into the Settlement Agreement pursuant to which the Company and SunEdison released these claims and substantially all other intercompany claims between the Company and SunEdison upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017. Therefore, any claims with respect to these avoidance actions have been released.



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20. RELATED PARTIES

As discussed in Note 1. Nature of Operations and Basis of Presentation, prior to the consummation of the Merger, TerraForm Power was a controlled affiliate of SunEdison, Inc. As a result of the consummation of the Merger on October 16, 2017, a change of control of TerraForm Power occurred, and Orion Holdings, which is an affiliate of Brookfield, now holds 51% of the voting securities of TerraForm Power. As a result of the Merger closing, TerraForm Power is no longer a controlled affiliate of SunEdison, Inc. and is now a controlled affiliate of Brookfield.

SunEdison Bankruptcy and Settlement with SunEdison    

As discussed in Note 1. Nature of Operations and Basis of Presentation, TerraForm Power entered into the Settlement Agreement with SunEdison on March 6, 2017, which was approved by the Bankruptcy Court. The settlements, mutual intercompany releases and certain other terms and conditions became effective upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017. The effectiveness of these Settlement Agreement provisions has resolved claims between TerraForm Power and SunEdison, including, among other things, claims of SunEdison against the Company for alleged fraudulent and preferential transfers and claims of the Company against SunEdison, including those outlined in the initial proof of claim filed by the Company in the SunEdison Bankruptcy on September 25, 2016 and on October 7, 2016. Under the Settlement Agreement, all such claims have been mutually released. Moreover, with certain limited exceptions, any agreements between SunEdison Debtors and SunEdison parties to the Settlement Agreement on the one hand and the Company on the other hand have been deemed rejected without further liability, claims or damages on the part of the Company. These exceptions included directors' and officers' liability insurance allocation agreements and certain corporate and project-level transition services agreements.

Historical Management Services Agreement with SunEdison

Historically, general and administrative expenses - affiliate primarily represented costs incurred by SunEdison for services provided to the Company pursuant to the management services agreement (the "SunEdison MSA"). Pursuant to the SunEdison MSA, SunEdison agreed to provide or arrange for other service providers to provide management and administrative services to the Company. As consideration for the services provided, the Company agreed to pay SunEdison a base management fee equal to 2.5% of the Company's cash available for distribution in 2015, 2016 and 2017 but not to exceed $4.0 million in 2015, $7.0 million in 2016 or $9.0 million in 2017. Subsequent to the SunEdison Bankruptcy, SunEdison continued to provide some of these services, including services related to information technology, human resources, tax, treasury, finance and controllership, but stopped providing or reimbursing the Company for other services.

The Company entered into a corporate-level transition services agreement with SunEdison on September 7, 2017 that covered the services that SunEdison continued to provide under the SunEdison MSA and retroactively applied to transition services provided since February 1, 2017. The Company paid SunEdison certain monthly fees in exchange for these services at rates consistent with past practice. Amounts incurred by the Company under this transition services agreement with SunEdison and by SunEdison under the SunEdison MSA totaled $4.5 million, $12.0 million and $54.3 million for the years ended December 31, 2017, 2016 and 2015, respectively, and are reported within general and administrative expenses - affiliate in the consolidated statements of operations. As discussed above, the SunEdison MSA was rejected without further liability, claims or damages on the part of the Company pursuant to the Settlement Agreement upon the closing of the Merger. The corporate-level transition services agreement was extended through the end of the fourth quarter of 2017 with respect to certain information technology services. Amounts incurred for these services subsequent to the Merger closing date on October 16, 2017 are included within general and administrative expenses in the consolidated statement of operations since SunEdison was no longer an affiliate of the Company.

Historical O&M and Asset Management Services with SunEdison

O&M services, as well as asset management services, were historically provided to the Company substantially by SunEdison pursuant to contractual agreements. The Company has completed its transition away from SunEdison for these services, with the exception of services provided to its 101.6 MW renewable energy facility in Chile. In the first half of 2017, the Company entered into certain transition services agreements with SunEdison to facilitate this transition. These transition services agreements allowed the Company, among other things, to hire employees of SunEdison that were performing these project-level services for the Company and to terminate project-level asset management and O&M services on 10 days advance notice. Total costs incurred for O&M and asset management services from SunEdison were $17.6 million, $26.7 million and


143


$19.9 million during the years ended December 31, 2017, 2016 and 2015, respectively, and are reported as cost of operations - affiliate in the consolidated statements of operations. Amounts incurred for O&M and asset management services from SunEdison subsequent to the Merger closing date on October 16, 2017 are included within cost of operations in the consolidated statement of operations since SunEdison was no longer an affiliate of the Company.

In addition, in conjunction with the First Wind Acquisition in 2015, SunEdison committed to reimburse the Company for capital expenditures and O&M labor fees in excess of budgeted amounts (not to exceed $53.9 million through 2019) for certain of its wind power plants. During the year ended December 31, 2015, the Company received contributions pursuant to this agreement of $4.3 million. The total amount related to capital expenditures of $50.0 million was initially recognized in renewable energy facilities as a prepaid warranty as the amount was part of the consideration paid on the acquisition date. As a result of the SunEdison Bankruptcy, the Company recorded a loss of $45.4 million during the year ended December 31, 2015 related to the write-off of the remaining balance of the prepaid warranty, which was net of depreciation expense of $1.9 million and capital expenditure reimbursements received of $2.7 million, and is reported as loss on prepaid warranty - affiliate in the consolidated statement of operations. As a result of the SunEdison Bankruptcy, no contributions were received during 2016 or 2017.

Historical Engineering, Procurement and Construction Contracts and Module Warranties

SunEdison served as the prime construction contractor for most of the Company's renewable energy facilities acquired from SunEdison pursuant to engineering, procurement and construction contracts with the Company's project-level subsidiaries. The Company also generally obtained solar module warranties from SunEdison, including workmanship warranties and output guarantees, for those solar facilities that the Company acquired from SunEdison that utilized SunEdison modules. Third party insurance was procured by SunEdison to back-stop payment of warranty claims for SunEdison modules purchased from January of 2011 through January of 2017.

During the first quarter of 2017, the Company received $7.0 million from SunEdison in satisfaction of outstanding claims made under engineering, procurement and construction contracts, of which $4.8 million related to the Company's renewable energy facility located in Chile and compensated the relevant project company as the facility's performance during the warranty period was below that guaranteed by an affiliate of SunEdison under the applicable EPC contract. These receipts were treated as equity contributions from SunEdison within Net SunEdison investment on the consolidated statement of stockholders' equity for the year ended December 31, 2017. As discussed above, pursuant to the Settlement Agreement entered into with SunEdison, and upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017, these construction and related contracts were rejected without further liability, claims or damages on the part of the Company.

Historical Interest Payment Agreement with SunEdison

Since the Company's initial public offering (“IPO”) on July 23, 2014, the Company was a party to an interest payment agreement with SunEdison, pursuant to which SunEdison would pay a portion of the scheduled interest payments on certain corporate-level indebtedness. The Company received equity contributions totaling $8.0 million and $10.6 million from SunEdison pursuant to this agreement during the years ended December 31, 2016 and 2015, respectively. The 2016 contribution was received in the first quarter of 2016 and accrued for during fiscal 2015. As of the first quarter of 2016, the Company had received a cumulative amount of $24.0 million under this agreement from SunEdison with $24.0 million of scheduled payments due in future periods. The Company did not receive any payments from SunEdison pursuant to this agreement subsequent to the first quarter of 2016. As discussed above, pursuant to the Settlement Agreement entered into with SunEdison, and upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017, this agreement was rejected without further liability, claims or damages on the part of the Company.

Historical Support Agreement and Intercompany Agreement with SunEdison

The Company entered into a project support agreement with SunEdison (the “Support Agreement”) on July 23, 2014, which provided the Company the option to purchase additional renewable energy facilities from SunEdison and also provided the Company a right of first offer with respect to certain other renewable energy facilities. During the years ended December 31, 2016 and 2015, the Company acquired renewable energy facilities with a combined nameplate capacity of 19.2 MW and 350.9 MW, respectively, from SunEdison under the Support Agreement (see Note 3. Transactions Between Entities Under Common Control). The Company did not acquire any renewable energy facilities from SunEdison under the Support Agreement during the year ended December 31, 2017.


144



In connection with the First Wind Acquisition, the Company and SunEdison entered into an agreement (the “Intercompany Agreement”) pursuant to which the Company was granted the option to purchase additional renewable energy facilities in the First Wind pipeline from SunEdison. During the year ended December 31, 2015, the Company acquired renewable energy facilities with a combined nameplate capacity of 222.6 MW from SunEdison under the Intercompany Agreement (see Note 3. Transactions Between Entities Under Common Control). The Company did not acquire any renewable energy facilities from SunEdison under the Intercompany Agreement during the years ended December 31, 2017 or 2016.

As discussed above, pursuant to the Settlement Agreement entered into with SunEdison, and upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017, the Support Agreement and Intercompany Agreement were rejected without further liability, claims or damages on the part of the Company.

The Company continues to maintain a call right over 0.5 GW (net) of operating wind power plants that are owned by a warehouse vehicle that was owned and arranged by SunEdison (the “AP Warehouse”). SunEdison sold its equity interest in the AP Warehouse to an unaffiliated third party in 2017.

Insurance Allocation Agreements

     The Company, TerraForm Global, Inc., SunEdison and certain of their respective directors and officers shared $150.0 million of directors’ and officers’ liability insurance policies that covered the period from July 15, 2015 to July 14, 2016 (the “D&O Insurance”). SunEdison and the independent directors of SunEdison (the “SUNE D&O Parties”) entered into an agreement, dated March 27, 2017 and amended on June 7, 2017, with the Company, TerraForm Global, Inc., their respective current directors (as of that date) and certain of their respective current officers (as of that date) (the “YieldCo D&O Parties”) related to the D&O Insurance, which included, among other things, an agreement by SunEdison to consent to proposed settlements of up to $32.0 million to be funded from the D&O Insurance for certain lawsuits against the YieldCo D&O Parties. The agreement was approved by the Bankruptcy Court on June 28, 2017.

On August 31, 2017, the Company, TerraForm Global, Inc., SunEdison and certain of their respective current and former directors and officers entered into a second agreement related to the D&O insurance, which provided, among other things, that no party to the second D&O insurance allocation agreement would object to the settlement of the Chamblee Class Action (as discussed in Note 19. Commitments and Contingencies) with the use of $13.63 million of the D&O insurance. On September 11, 2017, the Bankruptcy Court granted approval of the second D&O insurance allocation. In connection with the second D&O insurance allocation agreement, the Company and TerraForm Global, Inc. entered into an agreement pursuant to which TerraForm Global, Inc. agreed to indemnify and reimburse the Company for certain legal costs and expenses related to the defense or settlement of the Chamblee Class Action that are not covered by the D&O insurance.

In addition to the insurance allocation agreements, from time to time, the Company agreed to orders or stipulations with SunEdison and TerraForm Global, Inc. in connection with the SunEdison Bankruptcy related to, among other things, insurance proceeds, interim operating protocols, bankruptcy filing protocols and other matters.

Due to affiliates, net and due from affiliate

As of December 31, 2016, the Company had a net payable to SunEdison of $16.7 million, which is reported as due to affiliates, net in the consolidated balance sheet. As discussed above, under the Settlement Agreement, the settlements and mutual intercompany releases became effective upon the consummation of the Merger with affiliates of Brookfield on October 16, 2017, and as a result, the Company wrote-off $15.7 million of payables to SunEdison as of such date. The write-off was recognized in additional paid-in capital as the entire settlement with SunEdison was accounted for as an equity transaction.

The $4.0 million due to affiliates, net amount reported in the consolidated balance sheet as of December 31, 2017 represents a $3.4 million payable to an affiliate of Brookfield for the quarterly base management fee that was payable pursuant to the Brookfield MSA (as defined and discussed below under Brookfield Master Services Agreement) and $0.6 million of accrued standby fee interest that was payable to a Brookfield affiliate under the Sponsor Line Agreement. As of December 31, 2017, the Company also had a $4.4 million receivable from TerraForm Global, Inc. as a result of payments made by the Company on its behalf regarding rent for its shared corporate headquarters, compensation for certain employees that provided services to both companies during 2017 and certain other information technology services. On December 28, 2017, TerraForm Global, Inc. merged with and into an affiliate of Brookfield, with TerraForm Global, Inc. continuing as the surviving


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corporation in the merger, and it became a wholly-owned subsidiary of Orion Holdings. As a result, TerraForm Global, Inc. was no longer a controlled affiliate of SunEdison and instead was a controlled affiliate of Brookfield as of December 31, 2017 (and was again an affiliate of the Company). There is no right of set-off with respect to the receivable from TerraForm Global, Inc. and the payables to the Brookfield affiliates, and thus this receivable is separately reported in due from affiliate in the consolidated balance sheet.

As a result of the SunEdison Bankruptcy, the Company recognized an $11.3 million loss on investment within loss on investments and receivables - affiliate in the consolidated statement of operations for the year ended December 31, 2015 as a result of residential project cancellations. Further, the Company recognized an additional $1.8 million, $3.3 million and $4.8 million loss within loss on investments and receivables - affiliate for the years ended December 31, 2017, 2016 and 2015, respectively, related to the write-off of outstanding receivables from the SunEdison Debtors.

Net SunEdison Investment

During the years ended December 31, 2017, 2016 and 2015, SunEdison made net contributions to Terra LLC pursuant to the related party agreements discussed above and in connection with drop down acquisitions. The following table illustrates the detail of Net SunEdison investment for the years ended December 31, 2017, 2016 and 2015 as reported on the consolidated statements of stockholders' equity:
 
 
Year ended December 31,
(in thousands)
 
2017
 
2016
 
2015
General and administrative expenses - affiliate1
 
$
6,154

 
$
7,666

 
$
51,330

Failed deal costs 2
 

 

 
6,069

Interest payment agreement3
 

 

 
18,597

First Wind capital expenditures and O&M labor fees4
 

 

 
4,303

TerraForm Power, Inc. equity awards distributed to SunEdison5
 
(3,372
)
 
(3,369
)
 
(10,509
)
Deemed contribution related to acquisitions from SunEdison6
 

 
19,517

 
41,773

Lindsay debt repayment7
 

 

 
40,306

Other8
 
6,986

 
1,586

 
1,532

Net SunEdison investment
 
$
9,768

 
$
25,400

 
$
153,401

———
(1)
Represents costs incurred by SunEdison for services provided to the Company pursuant to the SunEdison MSA in excess of cash paid or payable to SunEdison, as well as stock-based compensation expense related to equity awards in the stock of SunEdison, Inc. and TerraForm Global, Inc. that was allocated to the Company (as discussed in Note 16. Stock-based Compensation). The Company did not pay SunEdison the $7.0 million base management fee that it was contractually obligated to in 2016 as the amount the Company had to pay third party service providers to cover the services that SunEdison stopped providing exceeded this contractual amount. Since this fee was not paid to SunEdison as of December 31, 2016, it was recorded within Due to affiliates, net and as a reduction to the net equity contribution from SunEdison. Pursuant to the Settlement Agreement and upon the consummation of the Merger on October 16, 2017, this liability was written off to additional paid-in capital as discussed under Due to affiliates, net above.
(2)
Represents acquisition costs related to failed deals that were paid by SunEdison. Such costs were reimbursable by SunEdison under the SunEdison MSA.
(3)
Represents contributions received pursuant to an interest payment agreement with SunEdison. $8.0 million of the amount for the year ended December 31, 2015 was not received in cash from SunEdison until February 3, 2016 and a receivable from SunEdison was recorded as of December 31, 2015.
(4)
Represents contributions received for capital expenditures and O&M labor fees in excess of budgeted amounts for certain of the Company's wind power plants, which SunEdison committed to reimburse the Company for in conjunction with the First Wind Acquisition.
(5)
Represents stock-based compensation cost related to equity awards in the Company's stock which was allocated to SunEdison and TerraForm Global, Inc.
(6)
Represents the difference between the cash purchase price and historical cost of the net assets acquired from SunEdison for projects that achieved final funding during the respective year.
(7)
SunEdison repaid the remaining outstanding principal balance and interest due on the SunE Perpetual Lindsay construction term loan on the Company's behalf as required pursuant to the terms of a project investment agreement entered into prior to the IPO of the Company.
(8)
Amount for the year ended December 31, 2017 represents cash received from SunEdison in satisfaction of outstanding claims made under engineering, procurement and construction contracts as discussed above.



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Historical Distributions to SunEdison

During the year ended December 31, 2015, Terra LLC paid distributions of $58.3 million to SunEdison, its Class B unit holder at that time. No distributions were paid to SunEdison during the years ended December 31, 2017 or 2016.

Historical Incentive Distribution Rights of SunEdison

Immediately prior to the completion of the IPO on July 23, 2014, Terra LLC entered into the Amended and Restated Operating Agreement of Terra LLC which granted SunEdison 100% of the IDRs of Terra LLC. IDRs represented the right to receive increasing percentages (15.0%, 25.0% and 50.0%) of Terra LLC’s quarterly distributions after the Class A Units, Class B units and Class B1 units of Terra LLC (as applicable) received quarterly distributions in an amount equal to $0.2257 per unit and the target distribution levels were achieved. SunEdison held 100% of the IDRs from the completion of the IPO up until the consummation of the Merger. There were no payments for IDRs made by the Company during the years ended December 31, 2017, 2016 and 2015.

As discussed in Note 1. Nature of Operations and Basis of Presentation, SunEdison transferred all of the outstanding IDRs of Terra LLC held by SunEdison or certain of its affiliates to Brookfield IDR Holder at the effective time of the Merger, and the Company and Brookfield IDR Holder entered into an amended and restated limited liability company agreement of Terra LLC as discussed below under Brookfield Sponsorship Transaction, which adjusted the distribution thresholds and percentages applicable to the Terra LLC IDRs.

Brookfield Sponsorship Transaction

As discussed in Note 1. Nature of Operations and Basis of Presentation, pursuant to the Merger Agreement, at or prior to the effective time of the Merger that occurred on October 16, 2017, the Company and Orion Holdings (or one of its affiliates), among other parties, entered into a suite of agreements providing for sponsorship arrangements, as are more fully described below.

Brookfield Master Services Agreement

In connection with the consummation of the Merger, the Company entered into a master services agreement (the “Brookfield MSA”) with Brookfield and certain affiliates of Brookfield (collectively, the “MSA Providers”) pursuant to which the MSA Providers provide certain management and administrative services to the Company, including the provision of strategic and investment management services. As consideration for the services provided or arranged for by Brookfield and certain of its affiliates pursuant to the master services agreement, the Company will pay a base management fee on a quarterly basis that will be paid in arrears and calculated as follows:

for each of the first four quarters following the closing date of the Merger, a fixed component of $2.5 million per quarter (subject to proration for the quarter including the closing date of the Merger) plus 0.3125% of the market capitalization value increase for such quarter;
for each of the next four quarters, a fixed component of $3.0 million per quarter plus 0.3125% of the market capitalization value increase for such quarter; and
thereafter, a fixed component of $3.75 million per quarter plus 0.3125% of the market capitalization value increase for such quarter.

For purposes of calculating the quarterly payment of the base management fee, the term market capitalization value increase means, for any quarter, the increase in value of the Company’s market capitalization for such quarter, calculated by multiplying the number of outstanding shares of Class A common stock as of the last trading day of such quarter by the difference between (x) the volume-weighted average trading price of a share of Class A common stock for the trading days in such quarter and (y) $9.52. If the difference between (x) and (y) in the market capitalization value increase calculation for a quarter is a negative number, then the market capitalization value increase is deemed to be zero.

Pursuant to the Brookfield MSA, the Company recorded a $3.4 million charge within general and administrative expenses - affiliate in the consolidated statement of operations for the year ended December 31, 2017 with an offsetting payable within due to affiliates, net in the consolidated balance sheet as of December 31, 2017.



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Relationship Agreement

In connection with the consummation of the Merger, the Company entered into a relationship agreement (the “Relationship Agreement”) with Brookfield, which governs certain aspects of the relationship between Brookfield and the Company. Pursuant to the Relationship Agreement, Brookfield agrees that the Company will serve as the primary vehicle through which Brookfield and certain of its affiliates will own operating wind and solar assets in North America and Western Europe and that Brookfield will provide, subject to certain terms and conditions, the Company with a right of first offer on certain operating wind and solar assets that are located in such countries and developed by persons sponsored by or under the control of Brookfield.

Governance Agreement

In connection with the consummation of the Merger, the Company entered into a governance agreement (the “Governance Agreement”) with Orion Holdings and any controlled affiliate of Brookfield (other than the Company and its controlled affiliates) that by the terms of the Governance Agreement from time to time becomes a party thereto. The Governance Agreement establishes certain rights and obligations of the Company and controlled affiliates of Brookfield that own voting securities of the Company relating to the governance of the Company and the relationship between such affiliates of Brookfield and the Company and its controlled affiliates.

Brookfield Registration Rights Agreement

The Company also entered into a registration rights agreement (the “Brookfield Registration Rights Agreement”) on October 16, 2017 with Orion Holdings. The Brookfield Registration Rights Agreement governs Orion Holdings’ and the Company’s rights and obligations with respect to the registration for resale of all or a part of the Class A shares that Orion Holdings now holds following the Merger.

New Terra LLC Agreement

As discussed above, SunEdison transferred all of the outstanding IDRs of Terra LLC held by SunEdison or certain of its affiliates to Brookfield IDR Holder at the effective time of the Merger, and the Company and Brookfield IDR Holder entered into an amended and restated limited liability company agreement of Terra LLC (the “New Terra LLC Agreement”). The New Terra LLC Agreement, among other things, resets the IDR thresholds of Terra LLC to establish a first distribution threshold of $0.93 per share of Class A common stock and a second distribution threshold of $1.05 per share of Class A common stock. As a result of this amendment and restatement, amounts distributed from Terra LLC will be distributed on a quarterly basis as follows:

first, to the Company in an amount equal to the Company’s outlays and expenses for such quarter;
second, to holders of Class A units, until an amount has been distributed to such holders of Class A units that would result, after taking account of all taxes payable by the Company in respect of the taxable income attributable to such distribution, in a distribution to holders of shares of Class A common stock of $0.93 per share (subject to adjustment for distributions, combinations or subdivisions of shares of Class A common stock) if such amount were distributed to all holders of shares of Class A common stock;
third, 15% to the holders of the IDRs and 85% to the holders of Class A units until a further amount has been distributed to holders of Class A units in such quarter that would result, after taking account of all taxes payable by the Company in respect of the taxable income attributable to such distribution, in a distribution to holders of shares of Class A common stock of an additional $0.12 per share (subject to adjustment for distributions, combinations or subdivisions of shares of Class A common stock) if such amount were distributed to all holders of shares of Class A common stock; and
thereafter, 75% to holders of Class A units and 25% to holders of the IDRs.
    
21. SEGMENT REPORTING

The Company has two reportable segments: Solar and Wind. These segments comprise the Company's entire portfolio of renewable energy facility assets and are determined based on the management approach. This approach designates the internal reporting used by management for making decisions and assessing performance as the source of the reportable segments. The Company’s operating segments consist of Distributed Generation, North America Utility and International


148


Utility that are aggregated into the Solar reportable segment and Northeast Wind, Central Wind and Hawaii Wind that are aggregated into the Wind reportable segment. The operating segments have been aggregated as they have similar economic characteristics and meet all of the aggregation criteria. Corporate expenses include general and administrative expenses, acquisition costs, interest expense on corporate-level indebtedness, stock-based compensation, depreciation, accretion and amortization expense and loss on extinguishment of corporate-level indebtedness. All net operating revenues for the years ended December 31, 2017, 2016 and 2015 were earned by the Company's reportable segments from external customers in the United States (including Puerto Rico), Canada, the United Kingdom and Chile.

The following table reflects summarized financial information concerning the Company’s reportable segments for the years ended December 31, 2017, 2016 and 2015:
 
 
Year Ended December 31, 2017
(In thousands)
 
Solar
 
Wind
 
Corporate
 
Total
Operating revenues, net
 
$
337,233

 
$
273,238

 
$

 
$
610,471

Depreciation, accretion and amortization expense
 
108,695

 
135,785

 
2,240

 
246,720

Other operating costs and expenses
 
66,642

 
105,817

 
150,569

 
323,028

Interest expense, net
 
70,439

 
77,398

 
114,166

 
262,003

Loss on extinguishment of debt, net
 

 
3,151

 
77,948

 
81,099

Gain on sale of renewable energy facilities
 
(37,116
)
 

 

 
(37,116
)
Other non-operating expenses (income), net
 
717

 
499

 
(10,535
)
 
(9,319
)
Income tax benefit1
 

 

 
(23,080
)
 
(23,080
)
Net income (loss)
 
$
127,856

 
$
(49,412
)
 
$
(311,308
)
 
$
(232,864
)
Cash Flows
 
 
 
 
 
 
 
 
Capital expenditures
 
$
302

 
$
7,670

 
$
420

 
$
8,392

Balance Sheet
 
 
 
 
 
 
 
 
Total assets2
 
2,897,036

 
3,400,858

 
89,127

 
6,387,021

 
 
Year Ended December 31, 2016
(In thousands)
 
Solar
 
Wind
 
Corporate
 
Total
Operating revenues, net
 
$
377,488

 
$
277,068

 
$

 
$
654,556

Depreciation, accretion and amortization expense
 
115,050

 
126,735

 
1,580

 
243,365

Other operating costs and expenses
 
140,459

 
91,613

 
90,142

 
322,214

Interest expense, net
 
97,123

 
85,744

 
127,469

 
310,336

Other non-operating (income) expenses, net
 
(1,017
)
 
1,126

 
19,545

 
19,654

Income tax expense1
 

 

 
494

 
494

Net income (loss)
 
$
25,873

 
$
(28,150
)
 
$
(239,230
)
 
$
(241,507
)
Cash Flows
 
 
 
 
 
 
 
 
Capital expenditures
 
$
32,132

 
$
12,177

 
$
1,560

 
$
45,869

Balance Sheet
 
 
 
 
 
 
 
 
Total assets2
 
3,595,387

 
3,609,471

 
501,007

 
7,705,865



149


 
 
Year Ended December 31, 2015
(In thousands)
 
Solar
 
Wind
 
Corporate
 
Total
Operating revenues, net
 
$
346,033

 
$
123,473

 
$

 
$
469,506

Depreciation, accretion and amortization expense
 
117,727

 
43,392

 
191

 
161,310

Other operating costs and expenses
 
65,515

 
89,831

 
147,336

 
302,682

Interest expense, net
 
71,351

 
6,991

 
89,463

 
167,805

Other non-operating expenses, net
 
13,986

 
6,682

 
38,417

 
59,085

Income tax benefit1
 

 

 
(13,241
)
 
(13,241
)
Net income (loss)
 
$
77,454

 
$
(23,423
)
 
$
(262,166
)
 
$
(208,135
)
Cash Flows
 
 
 
 
 
 
 
 
Capital expenditures
 
$
462,719

 
$
181,594

 
$
3,248

 
$
647,561

———
(1)
Income tax (benefit) expense is not allocated to the Company's Solar and Wind segments.
(2)
As of December 31, 2017 and 2016, respectively.

Operating Revenues, net
The following table reflects operating revenues, net for the years ended December 31, 2017, 2016 and 2015 by specific customers exceeding 10% of total operating revenue:
 
 
 
 
Year Ended December 31,
 
 
 
 
2017
 
2016
 
2015
(In thousands, except for percentages)
 
Segment
 
Amount
 
Percentage
 
Amount
 
Percentage
 
Amount
 
Percentage
Tennessee Valley Authority
 
Wind
 
$
79,773

 
13.1
%
 
$
73,068

 
11.2
%
 
N/A

 
N/A

San Diego Gas & Electric
 
Solar
 
63,905

 
10.5

 
65,709

 
10.0

 
$
67,562

 
14.4
%
———
N/A - This customer did not exceed 10% of total operating revenue for the period indicated above.
The following table reflects operating revenues, net for the years ended December 31, 2017, 2016 and 2015 by geographic location:
 
 
Year Ended December 31,
(In thousands)
 
2017
 
2016
 
2015
United States (including Puerto Rico)
 
$
519,551

 
$
528,513

 
$
368,117

Chile
 
31,282

 
28,065

 
27,148

United Kingdom
 
15,002

 
51,600

 
55,542

Canada
 
44,636

 
46,378

 
18,699

Total operating revenues, net
 
$
610,471

 
$
654,556

 
$
469,506




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Long-lived Assets, Net

Long-lived assets, net consist of renewable energy facilities and intangible assets as of December 31, 2017 and 2016. The following table is a summary of long-lived assets, net by geographic area:
 
 
As of December 31,
(In thousands)
 
2017
 
2016
United States (including Puerto Rico)
 
$
5,270,988

 
$
5,524,136

Chile
 
168,440

 
175,204

United Kingdom
 
17,284

 
16,045

Canada
 
422,999

 
419,978

Total long-lived assets, net
 
5,879,711

 
6,135,363

Current assets
 
341,536

 
893,016

Other non-current assets1
 
165,774

 
677,486

Total assets
 
$
6,387,021

 
$
7,705,865

———
(1)
As of December 31, 2016, includes $532.7 million and $19.5 million of non-current assets held for sale located in the United Kingdom and United States, respectively. There are no similar amounts as of December 31, 2017 as the sale of these renewable energy facilities closed in the first half of 2017.



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22. ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME

The following table presents the changes in each component of accumulated other comprehensive (loss) income, net of tax:
(In thousands)
 
Foreign Currency Translation Adjustments
 
Hedging Activities1
 
Accumulated Other Comprehensive (Loss) Income
Balance as of December 31, 2014
 
$
(1,149
)
 
$
(488
)
 
$
(1,637
)
Net unrealized (loss) gain arising during the period (net of zero tax benefit and $14,627 tax expense, respectively)
 
(18,446
)
 
26,913

 
8,467

Reclassification of net realized loss into earnings (net of zero tax impact)
 

 
4,663

 
4,663

Other comprehensive (loss) income
 
(18,446
)
 
31,576

 
13,130

Accumulated other comprehensive (loss) income
 
(19,595
)
 
31,088

 
11,493

Less: Other comprehensive loss attributable to non-controlling interests
 
(7,862
)
 
(3,545
)
 
(11,407
)
Balance as of December 31, 2015
 
$
(11,733
)
 
$
34,633

 
$
22,900

Net unrealized loss arising during the period (net of zero tax benefit and $406 tax expense, respectively)
 
(15,039
)
 
(86
)
 
(15,125
)
Reclassification of net realized loss into earnings (net of zero tax impact)2
 

 
15,967

 
15,967

Other comprehensive (loss) income
 
(15,039
)

15,881


842

Accumulated other comprehensive (loss) income
 
(26,772
)
 
50,514

 
23,742

Less: Other comprehensive (loss) income attributable to non-controlling interests
 
(4,639
)
 
5,469

 
830

Balance as of December 31, 2016
 
$
(22,133
)
 
$
45,045

 
$
22,912

Net unrealized gain arising during the period (net of tax expense of $3,238 and $2,428, respectively)
 
10,300

 
17,612

 
27,912

Reclassification of net realized loss (gain) into earnings (net of tax benefit of $8,858 and tax expense of $443, respectively)3
 
14,741

 
(2,247
)
 
12,494

Other comprehensive income
 
25,041

 
15,365

 
40,406

Accumulated other comprehensive income
 
2,908

 
60,410

 
63,318

Less: Other comprehensive income attributable to non-controlling interests
 
8,665

 
5,992

 
14,657

Plus: Reallocation from non-controlling interests as a result of SunEdison exchange4
 
(7,655
)
 
7,012

 
(643
)
Balance as of December 31, 2017
 
$
(13,412
)
 
$
61,430

 
$
48,018

———
(1)
See Note 13. Derivatives for further breakout of hedging gains and losses between interest rate swaps and commodity contracts.
(2)
Includes $16.9 million loss reclassification that occurred subsequent to the Company's discontinuation of hedge accounting for interest rate swaps within the U.K. Portfolio as discussed in Note 13. Derivatives.
(3)
The foreign currency translation adjustment amount represents the reclassification of the accumulated foreign currency translation loss for the U.K. Portfolio, as the Company's sale of this portfolio closed in the second quarter of 2017 as discussed in Note 4. Assets Held for Sale. The pre-tax amount of $23.6 million was recognized within gain on sale of renewable energy facilities in the consolidated statement of operations for the year ended December 31, 2017.
(4)
Represents reclassification of accumulated comprehensive (losses) income previously attributed to SunEdison's non-controlling interest in Terra LLC from non-controlling interests to accumulated other comprehensive income as of October 16, 2017, as a result of SunEdison's exchange of its Class B units in Terra LLC for Class A shares of TerraForm Power as discussed in Note 18. Non-controlling Interests.



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23. QUARTERLY FINANCIAL INFORMATION (UNAUDITED)

Quarterly results of operations for the year ended December 31, 2017 were as follows:
(In thousands, except per share data)
 
Q1
 
Q2(1)
 
Q3(2)
 
Q4(3)
Operating revenues, net
 
$
151,135

 
$
170,367

 
$
153,430

 
$
135,539

Operating income (loss)
 
12,068

 
25,547

 
24,686

 
(21,578
)
Interest expense, net
 
68,312

 
68,205

 
70,232

 
55,254

Net loss
 
(56,273
)
 
(680
)
 
(34,820
)
 
(141,091
)
Net (loss) income attributable to Class A common stockholders
 
(31,769
)
 
7,425

 
(26,546
)
 
(113,299
)
Weighted average basic Class A common shares outstanding
 
92,072

 
92,257

 
92,352

 
138,401

Weighted average diluted Class A common shares outstanding
 
92,072

 
92,745

 
92,352

 
138,401

Net (loss) earnings per weighted average Class A common share - basic and diluted
 
$
(0.37
)
 
$
0.06

 
$
(0.31
)
 
$
(0.82
)
———
(1)
The Company closed on the sale of the U.K. Portfolio during the second quarter of 2017 and recognized a gain on the sale of $37.1 million which is reflected within gain on sale of renewable energy facilities in the consolidated statement of operations.
(2)
The Company entered into a settlement agreement in 2017 with insurers of one of its wind power plants with respect to insurance proceeds related to a battery fire that occurred at the wind power plant in 2012, and the Company received the insurance proceeds in the fourth quarter of 2017. The receipt of the proceeds became probable in the third quarter of 2017, and the Company recognized a $5.3 million gain in other (income) expenses, net.
(3)
The fourth quarter of 2017 includes a $78.6 million loss on extinguishment of debt comprised of charges related to the Revolver, the Senior Notes due 2023 and the Midco Portfolio Term Loan (as discussed in Note 11. Long-term Debt), $27.0 million of charges recorded within general and administrative expenses related to success fees and advisory fees paid to third party advisers upon the closing of the Merger and a $7.0 million stock-based compensation charge recognized within general and administrative expenses as a result of the vesting of all previously unvested equity awards issued under the TerraForm Power 2014 Second Amended and Restated Long-term Incentive Plan upon the consummation of the Merger. These charges were partially offset by a $6.4 million increase recorded to the income tax benefit in the fourth quarter of 2017 to adjust amounts previously reported in 2016 as discussed in Note 12. Income Taxes and a $4 million gain recognized within general and administrative expenses as a result of the final settlement of the EMEC litigation as discussed in Note 19. Commitments and Contingencies.

Quarterly results of operations for the year ended December 31, 2016 were as follows:
(In thousands, except per share data)
 
Q1
 
Q2(1)
 
Q3(2)
 
Q4(3)
Operating revenues, net
 
$
153,917

 
$
187,301

 
$
178,118

 
$
135,220

Operating income (loss)
 
32,505

 
62,558

 
50,708

 
(56,794
)
Interest expense, net
 
68,994

 
101,299

 
72,818

 
67,225

Net loss
 
(33,505
)
 
(44,937
)
 
(27,711
)
 
(135,354
)
Net loss attributable to Class A common stockholders
 
(481
)
 
(20,907
)
 
(26,171
)
 
(82,288
)
Weighted average Class A common shares outstanding - basic and diluted
 
87,833

 
90,809

 
90,860

 
91,658

Net loss per weighted average Class A common share - basic and diluted
 
$
(0.01
)
 
$
(0.23
)
 
$
(0.29
)
 
$
(0.94
)
———
(1)
During the second quarter of 2016, the Company discontinued hedge accounting for interest rate swaps related to its U.K. Portfolio. This resulted in the reclassification of $16.9 million of losses from accumulated other comprehensive income into interest expense. Subsequent to the discontinuation of hedge accounting, the Company recognized additional unrealized losses of $13.7 million pertaining to these interest rate swaps during the second quarter that are also reported in interest expense.
(2)
The third quarter of 2016 includes a $3.3 million impairment charge due to the decision to abandon certain residential construction in progress assets that were not completed by SunEdison as a result of the SunEdison Bankruptcy. This charge is reflected within impairment of renewable energy facilities in the consolidated statement of operations. The third quarter of 2016 also includes $3.2 million of special interest for the Senior Notes due 2023, Senior Notes due 2025 and Revolver per the terms of the fourth supplemental indenture to the 2023 Indenture, third supplemental indenture to the 2025 Indenture and eighth amendment to the Revolver credit and guaranty agreement, respectively, and $5.2 million of unrealized losses pertaining to interest rate swaps for the U.K. Portfolio.
(3)
The fourth quarter of 2016 includes a $55.9 million goodwill impairment charge, a $15.7 million impairment charge within impairment of renewable energy facilities related to substantially all of the Company's portfolio of residential rooftop solar assets that were held for sale as of December 31, 2016, a $2.5 million loss on related party receivables and a $1.1 million loss on extinguishment of debt driven by a reduction of borrowing capacity for the Revolver and corresponding write-off of a portion of the unamortized deferred financing


153




costs due to the Company entering into the consent agreement and ninth amendment to the terms of the Revolver and a waiver agreement with the requisite lenders pertaining to third quarter reporting deliverables and compliance. The fourth quarter of 2016 also includes $8.6 million of special interest for the Senior Notes due 2023, Senior Notes due 2025 and Revolver, which was offset by $11.6 million of unrealized gains pertaining to interest rate swaps for the U.K. Portfolio. In addition, as discussed in Note 2. Summary of Significant Accounting Policies, during the fourth quarter of 2016, the Company revised the accretion period for its asset retirement obligations from the term of the related PPA agreement to the remaining useful life of the corresponding renewable energy facility, which resulted in the Company recording a $4.4 million adjustment to reduce previously reported accretion and depreciation expense. The Company also recorded a $5.9 million adjustment in the fourth quarter of 2016 to reduce previously reported cost of operations related to property tax expenses.

24. SUBSEQUENT EVENTS

Irrevocable Agreement to Launch Tender Offer for the Common Shares of Saeta Yield

On February 7, 2018, the Company announced that it intends to launch a voluntary tender offer (the “Tender Offer”) to acquire 100% of the outstanding shares of Saeta Yield, S.A. (“Saeta Yield”), a Spanish corporation and a publicly-listed European owner and operator of wind and solar assets, located primarily in Spain. The Tender Offer will be for 12.20 Euros per share of Saeta Yield. The Tender Offer is expected to be completed in the second quarter of 2018, subject to certain closing conditions.

In connection with this Tender Offer, on February 6, 2018, TERP Spanish HoldCo, S.L., a subsidiary of the Company, entered into an irrevocable undertaking agreement for the launch and acceptance of the takeover bid for the shares of Saeta Yield with Cobra Concesiones, S.L., a company incorporated under the laws of Spain (“Cobra”), and GIP II Helios, S.à r.l., a société à responsabilité limitée organized under the laws of the Grand Duchy of Luxembourg (“GIP”), as well as two separate irrevocable undertaking agreements with Mutuactivos, S.A.U., S.G.I.I.C., a company incorporated under the laws of Spain (“Mutuactivos”), and with Sinergia Advisors 2006, A.V., S.A., a company incorporated under the laws of Spain (“Sinergia” and, together with Cobra, GIP and Mutuactivos, the “Selling Stockholders”). Under the terms of these irrevocable undertaking agreements, the Selling Stockholders have irrevocably and unconditionally agreed to tender their combined 50.338% interest in Saeta Yield in the Tender Offer.

The Company’s acceptance of the shares of Saeta Yield tendered in the Tender Offer is conditioned upon the Company obtaining compulsory authorization required from the European Commission and Cobra and GIP irrevocably accepting the Tender Offer in respect of their shares of Saeta Yield representing no less than 48.222% of Saeta Yield’s voting share capital.
    
The aggregate value of the shares of Saeta Yield held by the Selling Stockholders is approximately $600 million. If the Company successfully acquires all of the remaining Saeta Yield shares in the Tender Offer, the aggregate purchase price (including the value of the Selling Stockholders shares) will be approximately $1.2 billion. Assuming a $1.2 billion acquisition price, the Company intends to finance the acquisition with a $400 million equity issuance of the Company’s Class A common stock (the “Equity Offering”) and the remaining $800 million will be financed from available liquidity, which the Company expects will include borrowings under the Sponsor Line Agreement and the New Revolver. The Company expects to repay these borrowings with a combination of sources, including new non-recourse financings of the Company’s currently unencumbered wind and solar assets and certain cash released from Saeta Yield’s assets.

In connection with the launch of the Tender Offer, the Company was required to post a bank guarantee (the “Bank Guarantee”) with the Spanish National Securities Market Commission (Comisión Nacional del Mercado de Valores) (the “CNMV”) for the maximum amount payable in the Tender Offer of approximately $1.2 billion. On March 6, 2018, TERP Spanish HoldCo entered into two letter of credit facilities (the “LC Agreements”) pursuant to which two banks posted the Bank Guarantee with the CNMV for the maximum amount payable in the Tender Offer. On March 6, 2018, TerraForm Power entered into two letter agreements (the “Letter Agreements” and together with the LC Agreements, the “Letter of Credit Facilities”) with those banks. The LC Agreements govern TERP Spanish HoldCo’s obligations to reimburse those banks upon any drawing under the Bank Guarantee. The Letter Agreements govern TerraForm Power’s obligation to utilize drawings on its New Revolver and Sponsor Line Agreement or proceeds from an equity offering of its Class A common stock to contribute funds to TERP Spanish HoldCo to enable TERP Spanish HoldCo to satisfy its reimbursement obligations under the LC Agreements. The Letter of Credit Facilities also contain customary fees, representations and warranties, covenants and events of default. Under the terms of the Letter of Credit Facilities, the Company is required to maintain minimum liquidity requirements of $500.0 million under the Sponsor Line Agreement and $400.0 million under the New Revolver. In addition, if any amount is


154




drawn under the Bank Guarantee, or if an event of default occurs under the Letter of Credit Facilities, we may be required to cash collateralize the entire amount of the Bank Guarantee that has not been drawn.

Backstop Agreement with Brookfield

On February 6, 2018, the Company entered into a support agreement with Brookfield. Pursuant to this agreement, Brookfield agreed that, if requested by the Company, Brookfield would provide a back-stop to the Company for up to 100% of the Equity Offering (such agreement, the “Back-Stop”) if the offering price per Class A share of the Company in the Equity Offering equals the five-day volume weighted average price of the Class A shares ending the trading day prior to the Company’s announcement of the Tender Offer, which was $10.66 per share. Brookfield’s obligations in relation to the provision of the Back-Stop under the support agreement are subject to successful commencement of the Tender Offer and to prior effectiveness of a registration statement, if required, that the Company would file in connection with the Equity Offering and such obligation would not apply to any Equity Offering commenced prior to May 1, 2018 or after September 30, 2018.

Information regarding certain other subsequent events have been included within the applicable notes to the Company's consolidated financial statements.






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EXHIBIT INDEX
Exhibit
Number
 
Description
 
 
 
2.1
 
 
 
 
2.2
 
 
 
 
2.3
 
 
 
 
2.4
 
 
 
 
3.1
 
 
 
 
3.2
 
 
 
 
4.1
 
 
 
 
4.2
 
 
 
 
4.3
 
 
 
 
4.4
 
 
 
 
4.5
 
 
 
 
4.6
 
 
 
 
4.7
 
 
 
 
4.8
 
 
 
 
4.9
 
 
 
 
10.1
 
 
 
 
10.2
 
 
 
 


156


10.3
 
 
 
 
10.4
 
 
 
 
10.5
 
 
 
 
 
 
 
10.6
 
 
 
 
10.7
 
 
 
 
10.8
 
 
 
 
10.9
 
 
 
 
10.10
 
 
 
 
10.11
 
 
 
 
10.12
 
 
 
 
10.13
 
 
 
 
10.14
 
 
 
 
10.15
 
 
 
 
10.16
 
 
 
 
10.17
 
 
 
 


157


10.18
 
 
 
 
10.19
 
 
 
 
10.20
 
 
 
 
10.21
 
 
 
 
10.22
 
 
 
 
21.1
 
 
 
 
23.1
 
 
 
 
31.1
 
 
 
 
31.2
 
 
 
 
32
 
 
 
 
101.INS
 
XBRL Instance Document
 
 
 
101.SCH
 
XBRL Taxonomy Extension Schema Document
 
 
 
101.CAL
 
XBRL Taxonomy Extension Calculation Linkbase Document
 
 
 
101.DEF
 
XBRL Taxonomy Extension Definition Linkbase Document
 
 
 
101.LAB
 
XBRL Taxonomy Extension Label Linkbase Document
 
 
 
101.PRE
 
XBRL Taxonomy Extension Presentation Linkbase Document
------
* This information is furnished and not filed for purposes of Sections 11 and 12 of the Securities Act of 1933 and Section 18 of the Securities Exchange Act of 1934.
** Annexes, schedules and exhibits have been omitted pursuant to Item 601(b)(2) of Regulation S-K. Registrant agrees to furnish a copy of any omitted attachment to the Securities and Exchange Commission on a confidential basis upon request.




158



    
SIGNATURES


Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 
 
 
 
TERRAFORM POWER, INC.
 
 
 
 
(Registrant)
 
 
 
 
 
 
Date:
March 7, 2018
 
 
By:
/s/ JOHN STINEBAUGH
 
 
 
 
 
John Stinebaugh
 
 
 
 
 
Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
Signature
 
Title
 
Date
 
 
 
 
 
/s/ JOHN STINEBAUGH
 
Chief Executive Officer
 
March 7, 2018
John Stinebaugh
 
(Principal executive officer)
 
 
 
 
 
 
 
/s/ MATTHEW BERGER
 
Chief Financial Officer
 
March 7, 2018
Matthew Berger
 
(Principal financial officer and principal accounting officer)
 
 
 
 
 
 
 
/s/ BRIAN LAWSON
 
Director and Chairman
 
March 7, 2018
Brian Lawson
 
 
 
 
 
 
 
 
 
/s/ CHRISTIAN S. FONG
 
Director
 
March 7, 2018
Christian S. Fong
 
 
 
 
 
 
 
 
 
/s/ HARRY GOLDGUT
 
Director
 
March 7, 2018
Harry Goldgut
 
 
 
 
 
 
 
 
 
/s/ RICHARD LEGAULT
 
Director
 
March 7, 2018
Richard Legault
 
 
 
 
 
 
 
 
 
/s/ MARK “MAC” MCFARLAND
 
Director
 
March 7, 2018
Mark ‘‘Mac’’ McFarland
 
 
 
 
 
 
 
 
 
/s/ SACHIN SHAH
 
Director
 
March 7, 2018
Sachin Shah
 
 
 
 


159
Exhibit
EXECUTION VERSION


Exhibit 10.19
March 6, 2018
Natixis, New York Branch
1251 Avenue of the Americas
New York, NY 10020
RE:
Continuing Agreement for Letters of Credit (the Agreement)

Ladies and Gentlemen:
In consideration of TERP Spanish HoldCo, S.L.’s (the “Applicant”) request that Natixis, New York Branch (“Issuer”) issue (at Issuer’s option and sole discretion) from time to time one or more irrevocable standby letters of credit (hereinafter, together with any amendments thereto, referred to as the “Credits”) following a request from the Applicant in accordance with the terms hereof, the parties hereto hereby undertake as follows:
1.Procedure for Application and Issuance; Certain Definitions.    In connection with the Offer (as defined below), during the period from the date of this Agreement until August 31, 2018 (the “L/C Commitment Period”), the Applicant may from time to time request, by delivering to the Issuer an application and agreement for the issuance or amendment of a Credit in the form of Exhibit I attached hereto (an “L/C Application”), completed to the reasonable satisfaction of the Issuer, that (a) the Issuer issue a Credit in favor of the Aval Provider (as defined below), notify the Aval Provider of the Applicant’s request for a Credit hereunder, and request that the Aval Provider issue a bank guarantee in the form attached hereto as Exhibit II (a “Bank Guarantee”), and (b) the Aval Provider issue a Bank Guarantee in favor of the beneficiaries listed in Exhibit II hereto.
Upon (a) satisfaction of all conditions set forth in Section 7 (Conditions Precedent); and (b) receipt of confirmation that after giving effect to the requested issuance, (i) the Stated Amount (as defined below) of all Credits issued and outstanding under this Agreement will not exceed the U.S. Dollar Equivalent (as defined below) of €497,619,261 (the “Facility Amount”) and (ii) no Default (as defined below) or Event of Default (as defined below) shall have occurred and be continuing, the Issuer will process such L/C Application in accordance with its customary procedures and shall promptly (1) issue the Credit requested thereby to the Aval Provider and (2) request that the Aval Provider issue a Bank Guarantee in favor of the beneficiaries listed in Exhibit II hereto (but in no event shall the Issuer be required to issue any Credit (or the Aval Provider be required to issue any Bank Guarantee) earlier than three (3) Business Days after its receipt of the applicable L/C Application, unless otherwise agreed in writing by the Issuer).
As used herein, the following terms shall have the following meanings:



“Agreement” has the meaning assigned to it in the reference section of this letter.
Anti-Corruption Laws” means the United States Foreign Corrupt Practices Act of 1977, the UK Bribery Act of 2010 and any related or similar laws, rules, regulations or guidelines, which in each case are issued, administered or enforced by the United States of America, the European Union and any of its member states or any Governmental Authority having jurisdiction over any member of the Group, or to which any member of the Group is subject.
Anti-Money Laundering Laws” means all applicable financial recordkeeping and reporting requirements and the money laundering statutes and the rules and regulations thereunder and any related or similar rules, regulations or guidelines, which in each case are issued, administered or enforced by any Governmental Authority having jurisdiction over any member of the Group, or to which any member of the Group is subject.
Applicable Rate” means 0.60% per annum.
“Applicant” has the meaning assigned to it in the introductory paragraph.
Articles of Association” means the charter documents, articles of association, operating agreements and other organizational documents of any Person.
Aval Provider” means Natixis S.A., Madrid Branch.
Backstop Agreements” means, collectively, (a) the Credit and Guaranty Agreement, dated as of October 17, 2017, among TPO, as borrower, TerraForm Power, LLC, as a guarantor, certain subsidiaries of TPO, as guarantors, the lenders party thereto from time to time, and HSBC Bank USA, National Association, as administrative agent and collateral agent (the “Revolver”); (b) the Credit Agreement, dated as of October 16, 2017, by and among Parent, as Borrower, and Brookfield Asset Management Inc., a corporation existing under the laws of the Province of Ontario, and Brookfield Finance Luxembourg S.ÀR.L., a société à responsabilité limitée organized under the laws of the Grand Duchy of Luxembourg, as Lenders (the “Sponsor Line”); and (c) the Support Agreement dated as of February 6, 2018 by and among Parent and Brookfield Asset Management Inc. (the “Support Agreement”).
Bail-In Action” means the exercise of any Write-Down and Conversion Powers by the applicable EEA Resolution Authority in respect of any liability of an EEA Financial Institution.
Bail-In Legislation” means, (a) with respect to any EEA Member Country implementing Article 55 of the Bank Recovery and Resolution Directive, the implementing law for such EEA Member Country from time to time which is described in the EU Bail-In Legislation Schedule and

2


(b) the then applicable Commission Delegated Regulation (if any) supplementing the Bank Recovery and Resolution Directive in relation to Article 55 thereof.
“Bank Guarantee” has the meaning assigned to it in this Section 1 (Procedure for Application and Issuance; Certain Definitions) above.
Bank Recovery and Resolution Directive” means Directive 2014/59/EU of the European Parliament and of the Council of the European Union.
Base Rate” means the prime commercial lending rate (which is not necessarily the lowest rate charged by Issuer on loans or other extensions of credit) published by Issuer from time to time, changing as and when said prime rate shall change. Any change in the rate of interest provided for herein based on a change in Issuer’s prime rate shall take effect on the date of the change in Issuer’s prime rate.
Board” means Board of Governors of the United States Federal Reserve System (or any successor thereto).
Business Day” means a day on which banks are open for business in New York and Madrid, Spain.
Capital Lease Obligations” means with respect to any Person means the obligations of such Person to pay rent or other amounts under any lease of (or other arrangement conveying the right to use) real or personal property, or a combination thereof, which obligations are required to be classified and accounted for as capital leases on a balance sheet of such Person under IFRS, and the amount of such obligations shall be the capitalized amount thereof determined in accordance with IFRS.
Change of Control” means the consummation of any transaction or series of transactions as a result of which Parent shall cease to own and control, (A) directly or indirectly, 100% of the securities having ordinary voting power for the election of directors (or persons performing similar functions) of TPO and NSF, excluding any incentive distribution rights in TPO (as in effect on the date hereof) (B) directly, or indirectly through TPO and NSF, 100% of the voting power of the membership interests and economic interests of the Applicant, excluding any incentive distribution rights in TPO (as in effect on the date hereof).  
“CNMV” means the Comisión Nacional del Mercado de Valores.
“Credit” has the meaning assigned to it in the introductory paragraph.
Credit Parties” means, collectively, Parent, TPO, NSF and Applicant.

3


Default” means any of the events specified in Section 8 (Default), whether or not any requirement for the giving of notice, the lapse of time, or both, has been satisfied.
Dollars”, “U.S. Dollars”, “USD$” and the sign “$” mean the lawful money of the United States of America.
“Draft” has the meaning assigned to it in Section 2 (Payment for Credits).
EEA Financial Institution” means (a) any credit institution or investment firm established in any EEA Member Country which is subject to the supervision of an EEA Resolution Authority, (b) any entity established in an EEA Member Country which is a parent of an institution described in clause (a) of this definition, or (c) any financial institution established in an EEA Member Country which is a subsidiary of an institution described in clauses (a) or (b) of this definition and is subject to consolidated supervision with its parent.
EEA Member Country” means any of the member states of the European Union, Iceland, Liechtenstein, and Norway.
EEA Resolution Authority” means any public administrative authority or any person entrusted with public administrative authority of any EEA Member Country (including any delegee) having responsibility for the resolution of any EEA Financial Institution.
EU Bail-In Legislation Schedule” means the EU Bail-In Legislation Schedule published by the Loan Market Association (or any successor person), as in effect from time to time.
“Effective Date” has the meaning assigned to it in Section 7.1 (Conditions Precedent).
Euros” and the sign “” mean the single currency of the Participating Member States.
Event of Default” means any of the events specified in Section 8 (Default), provided that any requirement for the giving of notice, the lapse of time, or both, has been satisfied
“Excluded Taxes” has the meaning assigned to it in Section 4 (Increased Costs and Taxes).
“Facility Amount” has the meaning assigned to it in this Section 1 (Procedure for Application and Issuance; Certain Definitions) above.
Facility Documents” means each of the following, in full force and effect and satisfactory to the Issuer, (a) this Agreement; (b) an intercreditor agreement with Banco Santander S.A. (the “Intercreditor Agreement”)(as the Issuer under the Applicant’s other letter of credit facility, dated as of the date hereof, relating to the Offer) (the “Santander Facility”); (c) those two certain comfort letter agreements, dated as of the date of this Agreement, between Issuer and Brookfield Asset

4


Management Inc. and Parent (respectively); and (d) other documents designated by Issuer acting reasonably.
Governmental Authority” means any nation or government, any state, provincial or other political subdivision thereof, and any agency, authority, instrumentality, regulatory body, court, central bank or other entity exercising executive, legislative, judicial, taxing, regulatory or administrative functions of or pertaining to government.
Group” means Applicant and its subsidiaries.
Hedging Obligations” means with respect to any specified Person, the obligations of such Person under:
(a)    interest rate swap agreements (whether from fixed to floating or from floating to fixed), interest rate cap agreements and interest rate collar agreements;
(b)    other agreements or arrangements designed to manage interest rates or interest rate risk; and
(c)    other agreements or arrangements designed to protect such Person against fluctuations in currency exchange rates or commodity prices.
Iberclear” means “Sociedad de Gestión de los Sistemas de Registro, Compensación y Liquidación de Valores, S.A. Unipersonal”), the entity responsible for the Spanish clearing and settlement system.
ICC Rules” has the meaning assigned to it in Section 14 (Practices for Documentary Credits).
“IFRS” means international accounting standards within the meaning of IAS Regulation 1606/2002 to the extent applicable to the relevant financial statements in effect as of the date of determination thereof.
Indebtedness” means with respect to any specified Person, any debt of such Person (excluding accrued expenses and trade payables), whether or not contingent:
(a)    in respect of borrowed money;
(b)    evidenced by bonds, notes, debentures or similar instruments;
(c)    in respect of letters of credit, banker’s acceptances or other similar instruments (or reimbursement agreements in respect thereof);
(d)    representing Capital Lease Obligations;

5


(e)    representing the balance deferred and unpaid of the purchase price of any property or services due more than sixty (60) days after such property is acquired or such services are completed; or
(f)    representing any Hedging Obligations,
if and to the extent any of the preceding items (other than letters of credit and Hedging Obligations) would appear as a liability upon a balance sheet of the specified Person prepared in accordance with IFRS.
Indemnified Person” has the meaning assigned to it in Section 5 (Indemnification).
“Indemnified Taxes” means taxes other than Excluded Taxes (defined below), including but not limited to, any and all current or future recording, stamp, documentary, excise, transfer, sales or similar taxes, charges or levies arising from any payment made under any Credit or from the execution, delivery or enforcement of, or otherwise with respect to, any Credit
Irrevocable Agreementsmeans, collectively (a) the Irrevocable Undertaking Agreement entered into in relation to the Offer dated as of February 6, 2018 between Applicant, Cobra Concesiones, S.L. and GIP II Helios, S.à r.l. (the “Cobra Irrevocable Agreement”); (b) the Irrevocable Undertaking Agreement entered into in relation to the Offer, dated as of February 6, 2018 between Applicant and Mutuactivos, S.A.U., S.G.I.I.C. (the “Mutuactivos Irrevocable Agreement”); and (c) that certain Irrevocable Undertaking Agreement entered into in relation to the Offer, dated as of February 6, 2018 between Applicant and Sinergia Advisors 2006, A.V., S.A. (the “Singergia Irrevocable Agreement”).
ISP” has the meaning assigned to it in Section 14 (Practices for Documentary Credits).
“Issuer” has the meaning assigned to it in the introductory paragraph.
“L/C Application” has the meaning assigned to it in this Section 1 (Procedure for Application and Issuance; Certain Definitions) above.
“L/C Commitment Period” has the meaning assigned to it in this Section 1 (Procedure for Application and Issuance; Certain Definitions) above.
Material Adverse Effect” means a material adverse change in or a material adverse effect on (a) the business, operations, properties, assets or condition (financial or otherwise) of the Applicant and the Credit Parties, taken as a whole, (b) the ability of Applicant to fully and timely perform its obligations under this Agreement, (c) the legality, validity, binding effect or enforceability against any Applicant of this Agreement or (d) the rights and remedies available to, or conferred upon, Issuer under this Agreement.

6


NSF” means Norrington Solar Farm Limited.
“Obligations” has the meaning assigned to it in Section 4 (Increased Costs and Taxes).
Offer” means Applicant’s takeover bid which has been launched for all of the outstanding shares of Saeta Yield, S.A. (“SAY”), and the SAY shareholders potentially accepting the Offer, all in accordance with Royal Decree 1066/2007, of 27 July, on the rules applicable to public takeover bids for securities (Real Decreto 1066/2007, de 27 de julio, sobre el régimen de las ofertas públicas de adquisición de valores –“RD 1066/2007”).
“Offer Documents” means the final documentation for the Offer, including the authorization request to launch the Offer submitted to CNMV, the announcement of the Offer and the Offer document (folleto informativo) in the form approved by the CNMV.
Parent” means TerraForm Power, Inc.
Participating Member State” means any member state of the European Union that has the Euro as its lawful currency in accordance with legislation of the European Union relating to Economic and Monetary Union.
Patriot Act has the meaning assigned to it in Section 25 (Patriot Act).
Person” means an individual, partnership, corporation, limited liability company, business trust, joint stock company, trust, unincorporated association, joint venture, Governmental Authority or other entity of whatever nature.
“Regulation U” means Regulation U of the Board, as in effect from time to time and all official rulings and interpretations thereunder or thereof.
Reimbursement Due Date” means the date that is forty-five (45) days from the date of any Draft under a Credit, whether such Draft is presented to Issuer before, on, or, if in accordance with applicable law or letter of credit practice, after the expiry date of any Credit.
Responsible Officer has the meaning assigned to it in Section 16(i)(a).
Restricted Party” means a Person that is: (i) listed on, or owned or controlled by a Person listed on, or acting on behalf of a Person listed on, any Sanctions List; (ii) located in, incorporated under the laws of, or owned or (directly or indirectly) controlled by, or acting on behalf of, a Person located in or organized under the laws of a country or territory that is the target of country-wide or territory-wide Sanctions; or (iii) otherwise a target of Sanctions (“target of Sanctions” signifying a Person with whom a United States Person or other national of a Sanctions Authority would be prohibited or restricted by law from engaging in trade, business or other activities).

7


Sanctions” means the economic sanctions laws, regulations, embargoes or restrictive measures administered, enacted or enforced by: (i) the United States government; (ii) the United Nations; (iii) the European Union or any of its member states; (iv) the respective governmental institutions and agencies of any of the foregoing, including, without limitation, the Office of Foreign Assets Control of the US Department of Treasury (“OFAC”), the United States Department of State, and Her Majesty’s Treasury (“HMT”); or (v) any jurisdiction in which any member of the Group operates (together the “Sanctions Authorities”).
Sanctions List” means the “Specially Designated Nationals and Blocked Persons” list maintained by OFAC, the Consolidated List of Financial Sanctions Targets and the Investment Ban List maintained by HMT, or any similar list maintained by, or public announcement of Sanctions designation made by, any of the Sanctions Authorities.
Spanish GAAP” means the requirements applicable to the financial statements and accounts set forth in the Spanish Stock Corporations Act (Ley de Sociedades de Capital), the General Accounting Plan in force in Spain and all resolutions issued by the ICAC (Instituto de Contabilidad y Auditoría de Cuentas), together with accounting principles, standards and practices which are generally accepted in Spain as at the date of the relevant financial statements or accounts.
Spot Rate” means the rate determined by Issuer as (a) the exchange rate reported by Bloomberg as of the end of the second TARGET2 Day preceding the date of payment or other determination, or (b) if such report is unavailable for any reason, the spot rate for the purchase of Euros with U.S. Dollars as in effect during the second Business Day preceding the date of payment or other determination in Issuer’s principal foreign exchange trading office for Euros; provided that Issuer may obtain such spot rate from another nationally recognized financial institution designated by Issuer if it does not have as of the applicable date of payment or other determination a spot buying rate for the purchase of Euros with U.S. Dollars.
Stated Amount” means, as it relates to any Credit, the maximum U.S. Dollar Equivalent amount from time to time available to be drawn thereunder.

TARGET Day” means any day on which TARGET2 (or, if such payment system ceases to be operative, such other payment system, if any, determined by Issuer to be a suitable replacement therefor) is open for the settlement of payments in Euros.
TARGET2” means the Trans-European Automated Real-time Gross Settlement Express
Transfer payment system which utilizes a single shared platform and which was launched on
November 19, 2007.

TPO” means TerraForm Power Operating, LLC.

8


UCP” has the meaning assigned to it in Section 14 (Practices for Documentary Credits).
U.S. Dollar Equivalent” means, at any time, (a) with respect to any amount denominated in U.S. Dollars, such amount, and (b) for any amount denominated in Euros, the equivalent amount thereof in U.S. Dollars as determined by Issuer based on the then-current Spot Rate applicable to the date of determination.
Write-Down and Conversion Powers” means, with respect to any EEA Resolution Authority, the write-down and conversion powers of such EEA Resolution Authority from time to time under the Bail-In Legislation for the applicable EEA Member Country, which write-down and conversion powers are described in the EU Bail-In Legislation Schedule.
2.    Payment for and Reduction of Credits; Payments in U.S. Dollars. Applicant agrees to reimburse Issuer, at Issuer’s office in New York, in U.S. Dollars, the amount of each draft or other request for payment (each, a “Draft”) drawn under a Credit on or before the applicable Reimbursement Due Date. To the extent that any Draft drawn under a Credit is payable in Euros, Applicant agrees to pay to Issuer, on or before the Reimbursement Due Date, at Issuer’s office in New York, the U.S. Dollar Equivalent of such amount in U.S. Dollars.
The Stated Amount of each Credit shall be reduced by the U.S. Dollar Equivalent amount of Drafts paid in respect thereof. Notwithstanding anything to the contrary contained in this Agreement, once so reduced, the Stated Amount of any Credit shall not be reinstated.
Applicant’s obligation to make payments in U.S. Dollars hereunder shall not be satisfied by any tender, or any recovery by Issuer pursuant to the Intercreditor Agreement or any judgment, which is expressed in or converted into any currency other than U.S. Dollars, except to the extent that such tender or recovery results in the actual receipt by Issuer in New York of the full amount of U.S. Dollars payable under this Agreement.
3.    Payment for Services Rendered. The Applicant agrees to pay Issuer’s and (without duplication) Aval Provider’s usual and customary charges for the opening of any Credit and issuance of any Bank Guarantee, for the negotiation of any Drafts paid and for any wire transfers.
In addition, Applicant shall pay Issuer in U.S. Dollars:
(a)
a one-time structuring fee on the third (3rd) Business Day following the Effective Date in an amount equal to 0.10% on the U.S. Dollar Equivalent of the Facility Amount, earned and due and payable upon the issuance of a Bank Guarantee pursuant to this Agreement;
(b)
a one-time upfront fee on the third (3rd) Business Day following the Effective Date in an amount equal to 0.10% on the U.S. Dollar Equivalent of the Facility Amount,

9


earned and due and payable upon the issuance of a Bank Guarantee pursuant to this Agreement;
(c)
on the last Business Day in each February, May, August and November, and on the last Business Day of the L/C Commitment Period, a fee in U.S. Dollars for such quarterly period (or portion thereof) then ending equal to the product of (1) (x) the U.S. Dollar Equivalent of the daily average Stated Amount of all Credits outstanding for the relevant quarterly period (or portion thereof) multiplied by (y) a fraction, the numerator of which is the number of days in such quarterly period (or portion thereof) and the denominator of which is 360, multiplied by (2) 0.60%; and
(d)
upon Issuer’s written demand, from and after the occurrence of an Event of Default or any event of default under any other direct agreements between Issuer and any of its affiliates (on the one hand) and a Credit Party (on the other hand) interest on any amounts payable hereunder (including any fees and any required reimbursement), at the then-prevailing interest rate hereunder (including the Applicable Rate) plus 2.00% to the date of payment by Applicant (said interest to be calculated on the basis of the actual number of days elapsed in a 360-day year); and
(e)
promptly upon Issuer’s written demand, all liabilities, charges and reasonable expenses (including reasonable and properly documented out-of-pocket attorneys’ fees and expenses) paid by or incurred by Issuer or Aval Provider in connection with each Credit or Bank Guarantee or this Agreement or the enforcement hereof.
Subject to the immediately following paragraph and Section 7 (Conditions Precedent) below, interest shall be payable on the U.S. Dollar Equivalent of any outstanding and unreimbursed honored Drafts or unreimbursed amounts due to the Issuer pursuant to this Agreement from the date on which the relevant amount is payable or Draft is paid by the Issuer (as applicable) until the date of repayment in full in U.S. Dollars and in immediately available funds at a rate equal to the Base Rate plus the Applicable Rate.
4.    Increased Costs and Taxes. If Issuer determines that the introduction or effectiveness of, or any change in, any law or regulation or compliance with any guideline or request (whether or not having the force of law) from any Governmental Authority which affects or would affect the amount of capital or reserves required or expected to be maintained by Issuer or any corporation controlling Issuer, and Issuer determines that the amount of such capital or reserves is increased by or based upon the existence of any Credit, then Applicant shall pay Issuer promptly upon Issuer’s written demand therefor, from time to time, additional amounts in U.S. Dollars sufficient in Issuer’s judgment to compensate for the increase. For the avoidance of doubt, Issuer’s certificate as to amounts due hereunder shall be conclusive, in the absence of manifest error.

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Any and all payments by or on account of any of Applicant’s obligations hereunder (the “Obligations”) shall be made free and clear of and without reduction or withholding for any Indemnified Taxes imposed by or within the jurisdiction of Applicant’s organization, or the jurisdiction from which payment hereunder is being made, provided that if Applicant shall be required by applicable law to deduct any Indemnified Taxes from such payments, then (a) the sum payable shall by increased as necessary so that after making all required deductions (including deductions applicable to additional sums payable under this section), Issuer receives an amount in U.S. Dollars equal to the sum it would have received had no such deductions been made, (b) Applicant shall make such deductions and (c) Applicant shall pay the full amount deducted to the relevant Governmental Authority in accordance with applicable law.
In addition, Applicant shall indemnify Issuer for, and hold Issuer harmless against, the full amount of Indemnified Taxes (including any taxes of any kind imposed or asserted by any jurisdiction on amounts payable under this section) imposed on or paid by Issuer or any affiliate of Issuer in respect of any liability (including penalties, interest and expenses) arising therefrom or with respect thereto, whether or not such Indemnified Taxes were correctly or legally asserted. Payment under this indemnity shall be made within thirty (30) days from the date Issuer makes written demand therefor.
Within thirty (30) days after the date of any payment of Indemnified Taxes, Applicant shall furnish to Issuer at Issuer’s address listed above, the original or a certified copy of a receipt evidencing such payment. In case of any payment hereunder by or on behalf of Applicant, if Applicant determines that no Indemnified Taxes are payable in respect thereof, Applicant shall, at Issuer’s request, furnish, or cause the payor to furnish, to Issuer an opinion of counsel acceptable to Issuer in form and substance acceptable to Issuer stating that such payment is exempt from Indemnified Taxes.
Notwithstanding anything to the contrary provided elsewhere in this Agreement and/or the relevant Credit, Applicant shall not be liable to make any payment to Issuer pursuant to this section for, or in relation to the following taxes: (i) taxes, franchise taxes and similar taxes measured by, or assessed against, Issuer’s net income, profit or capital and imposed by the jurisdiction in which Issuer’s principal office is situated; and (ii) any taxes that would not be imposed but for a connection between Issuer and such taxing jurisdiction, or any political subdivision thereof of taking authority therein, other than as a result of this Agreement or taxes imposed by the Kingdom of Spain (the “Excluded Taxes”).
5.    Indemnification. Applicant agrees to indemnify and hold Issuer, Aval Provider and Issuer’s and Aval Provider’s respective correspondents and each of Issuer’s and Aval Provider’s respective officers, directors, affiliates, employees, attorneys, advisors, consultants and agents (each an “Indemnified Person”) harmless against any and all claims, losses, costs, expenses, liabilities or

11


damages, including reasonable and properly documented out-of-pocket attorney fees and other dispute resolution expenses related thereto, howsoever arising from or in connection with (a) the issuance of a Credit or Bank Guarantee and/or the transactions contemplated hereby, (b) any payment or action taken or omitted to be taken in connection with a Credit or Bank Guarantee (including any action or proceeding seeking (i) to restrain any drawing under a Credit or Bank Guarantee, (ii) compel or restrain the payment of any amount or the taking of any other action under any Credit or Bank Guarantee, (iii) to compel or restrain the taking of any action under this Agreement or any other Facility Document or (iv) to obtain similar relief (including by way of interpleader, declaratory judgment, attachment or otherwise), regardless of who the prevailing party is in any such action or proceeding), (c) the enforcement of this Agreement or any other Facility Document or (d) any act or omission, whether rightful or wrongful, of any present or future de jure or de facto government or Governmental Authority or any other cause beyond Issuer’s or Aval Provider’s control, except in each of (a) through (d) above, to the extent that such claim, loss, cost, expense, liability or damage is found by a court of competent jurisdiction (in a final and non-appealable judgment) to have resulted from the willful misconduct or gross negligence of such Indemnified Person. Without limiting the generality of the foregoing, Applicant agrees to indemnify and hold each Indemnified Person harmless for any and all amounts adjudicated or otherwise ordered by any court or other tribunal to be payable by such Indemnified Person in connection with any Credits or Bank Guarantees to any beneficiary or its or their respective successors, assigns, heirs, and legal representatives, at any time before or after the expiration of the relevant Credit, including the principal amount of any and all Drafts drawn under the relevant Credit or Bank Guarantee, together with any and all interest thereon and any and all costs and expenses (including reasonable and properly documented out-of-pocket attorney fees) incurred by such Indemnified Person in connection with any such adjudication, or order; except to the extent that any such amount shall be adjudicated or ordered to be payable as a result of the willful misconduct or gross negligence of such Indemnified Person as determined by a court of competent jurisdiction by final and non-appealable judgment.
Promptly upon Issuer’s written demand, the Applicant shall compensate the Issuer for, and hold the Issuer harmless from, any loss, cost or expense incurred by it as a result of any failure by Applicant to make payment in U.S. Dollars of the U.S. Dollar Equivalent of any Draft under any Credit (or interest due thereon or other Obligations) denominated in Euros on its due date, including any foreign exchange losses.
Applicant agrees to pay promptly upon Issuer’s written demand from time to time all amounts owing under this section.
6.    No Setoffs or Deductions; Withdrawal from Applicant’s Account. Any and all amounts that may become due and payable to Issuer under this Agreement shall be paid by Applicant in U.S. Dollars in immediately available funds without defense, setoff, cross-claim, counterclaim or

12


deduction of any kind. Furthermore, Applicant authorizes Issuer to charge any account belonging to Applicant and held with Issuer, or any of Issuer’s affiliates, for any amount when due hereunder.
7.    Conditions Precedent.
7.1.    The effectiveness of this Agreement is subject to the prior or concurrent satisfaction of each of the conditions precedent set forth in this section (the date such conditions precedent are satisfied, the “Effective Date”) to the satisfaction of the Issuer:
(a)
Satisfactory completion of Issuer’s due diligence in connection with the transactions contemplated in the Facility Documents.
(b)
The Issuer shall have received this Agreement and other Facility Documents, in form and substance satisfactory to it, executed and delivered by each party thereto (as applicable) and such documentation shall be in full force and effect.
(c)
There shall have been delivered to the Issuer all of the following:
(i)
certified or unanimous consent resolutions signed by all shareholders of the Applicant and authorizing Applicant to enter into the Facility Documents to which it is a party and to take all action relative to such Facility Documents; authorizing the Applicant to sign the same; and containing the true signatures of such persons on which the Issuer may conclusively rely;
(ii)
copies of the Applicant’s and Parent’s Articles of Association as in effect on the Effective Date and an organizational chart of the Parent;
(iii)
a copy of a certificate of good standing issued by competent authorities in Spain and any other applicable jurisdiction (as applicable) (issued within the last thirty (30) days) for the Applicant and Parent;
(iv)
a certificate of incumbency for the Applicant and Parent; and
(v)
a certificate of a responsible officer of the Applicant and Parent with each of the appropriate attachments.
(d)
The Issuer shall have received a draft of the authorization request for the Offer and the Offer document (folleto informativo) to be submitted to the CNMV.
(e)
Delivery of certified, complete copies of all Backstop Agreements and Irrevocable Agreements (including any consents or waivers required in thereunder in connection with the transactions contemplated by the Facility Documents).

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(f)
Each of the representations and warranties made by the Applicant in Section 16(i) and by any Credit Party pursuant to the Facility Documents, Backstop Agreements and Irrevocable Agreements to which it is a party shall be true and correct in all material respects (except to the extent any such representation and warranty itself is qualified by “materiality,” “Material Adverse Effect” or similar qualifier, in which case, it shall be true and correct in all respects) on and as of the date such representation or warranty is made.
(g)
The Issuer shall have received a legal opinion of Sullivan & Cromwell LLP, as New York counsel to each of the Credit Parties, and a legal opinion of Uría Menéndez Abogados, S.L.P., as Spanish counsel to each of the Credit Parties, dated the Effective Date, covering such matters relating to the Facility Documents, Backstop Agreements, Irrevocable Agreements, the Offer, the Credit Parties and the transactions contemplated hereby as are usual and customary for financings of the type contemplated hereby as the Issuer shall reasonably request, in form and substance satisfactory to the Issuer.
(h)
The Issuer shall have received correct and complete copies of the unaudited de-consolidated audited financial statements of the Applicant for the fiscal year ended December 31, 2017, and accompanied by a Responsible Officer’s certificate dated the Effective Date, certifying that such financial statements fairly present in all material respects the financial condition and results of operations of the Applicant for such period and that such financial statements have been prepared in accordance with Spanish GAAP, consistently applied, as at the end of, and for, such period (subject to normal year-end audit adjustments).
(i)
[RESERVED].
(j)
The Issuer shall have received all documentation and other information requested by the Issuer in order to comply with requirements of bank regulatory authorities under applicable “know your customer” laws and Anti-Corruption Laws, Anti-Money Laundry Laws and the Patriot Act.
(k)
No Default or Event of Default shall have occurred and be continuing under this Agreement. No default or event of default (taking into account the proposed issuance of any requested Credit) shall have occurred and be continuing with respect to the Cobra Irrevocable Agreement, the Backstop Agreements or any other financing of Parent, TPO or Applicant.
(l)
Since December 31, 2017, there shall have been no event or occurrence, individually or in the aggregate, that has resulted in any Material Adverse Effect.

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7.2.    The obligation of Issuer to issue, amend, renew or extend any Credit hereunder is subject to the satisfaction (or waiver by Issuer), of the following conditions precedent:
(a)
The Applicant shall provide or cause to be provided to the Issuer evidence reasonably satisfactory to the Issuer (which may (at the Issuer’s reasonable discretion) include delivery of appropriate certificates from responsible officers of the Applicant and Parent), that (a) the Credit to be issued and (b) the issuance of the requested Credit, and the performance by the Applicant and Parent of their obligations with respect thereto, (i) do not conflict with any of the terms, covenants, conditions or provisions of, or constitute a default in respect of, or result in the creation or imposition of, or the obligation to create or impose, any lien (other than the security interests and liens created under the Facility Documents or liens permitted under the Facility Documents) on any of their respective properties pursuant to any contractual obligation, together with such additional information regarding the applicable Credit Party and beneficiary as the Issuer may reasonably request and (ii) is being issued in support of the Bank Guarantee in connection with the Offer.
(b)
Delivery of a request for a Credit in the form attached to the Facility Documents at least three (3) Business Days prior to requested issuance (which period shall be waived for any initial requests delivered on the Effective Date).
(c)
Except with respect to any Credit issued within three (3) Business Days following the Effective Date, payment of all fees due and payable under the Facility Documents with respect to the requested Credit.
(d)
No Default or Event of Default shall have occurred and be continuing under this Agreement. No default or event of default (taking into account the proposed issuance of any requested Credit) shall have occurred and be continuing with respect to the Cobra Irrevocable Agreement, the Backstop Agreements or any other financing of Parent, TPO or Applicant.
(e)
The Facility Documents, Backstop Agreements and Cobra Irrevocable Agreement shall be in full force and effect and the Offer shall not have been revoked, annulled or rescinded.
8.    Default. Should any of the following occur (each, an “Event of Default”);
(a)
Applicant defaults in respect of any payment due to Issuer or to any of Issuer’s subsidiaries or affiliates, whether such payment is due under this Agreement, in respect of any individual Credit or otherwise;

15


(b)
Applicant fails to perform or observe any other term or covenant of this Agreement in any material respect and such failure shall not have been remedied or waived within ten (10) Business Days;
(c)
Applicant fails to pay when due any other indebtedness for borrowed money, and such failure continues for more than the period of grace, if any, granted by the creditor(s) with respect to such indebtedness, or any other party to such indebtedness accelerates the maturity of any amount owing in respect thereof as a result of a default with respect to such indebtedness;
(d)
any representation or warranty made by Applicant or Parent or Brookfield Asset Management Inc. in any Facility Document or in any certificate or other document delivered in connection with any Facility Document is untrue in any material respect as of the date made;
(e)
(i) any “Event of Default” shall have occurred and be continuing under any Backstop Agreement; or (ii) any Credit Party shall have defaulted with respect to its obligations under the Cobra Irrevocable Agreement and such failure continues for more than the period of grace, if any, provided with respect thereto;
(f)
the Offer is withdrawn or cancelled;
(g)
(i) any Backstop Agreement or the Cobra Irrevocable Agreement shall cease, for any reason, to be in full force and effect (other than in accordance with its terms following payment and performance in full of all obligations thereunder (other than contingent indemnity and similar obligations which by their express terms survive termination thereof for which no claim has been made)), (ii) any Backstop Agreement or the Cobra Irrevocable Agreement is declared unenforceable by a Governmental Authority having jurisdiction over any party thereto or the subject matter thereof or is otherwise not in full force and effect (other than in accordance with its terms following payment and performance in full of all obligations thereunder (other than contingent indemnity and similar obligations which by their express terms survive termination thereof for which no claim has been made)), or (iii) any Credit Party shall challenge the enforceability of any Facility Document or shall assert in writing, or engage in any action or inaction based on any such assertion, that any provision of any of the Facility Documents has terminated or ceased to be or otherwise is not valid, binding and enforceable in accordance with its terms;
(h)
any final judgment or judgments for the payment of money (to the extent not paid or to the extent not covered by insurance as to which the relevant insurance company has acknowledged coverage) aggregating in excess of $10 million is or are

16


outstanding against Applicant and any one of such judgments has remained unpaid, unvacated, unbonded, or unstayed by appeal or otherwise for a period of sixty days from the date of its entry;
(i)
Applicant makes an assignment for the benefit of creditors, or admits in writing Applicant’s inability to pay Applicant’s debts as they become due, or commences a voluntary case under any applicable bankruptcy, insolvency or other similar law, or files any petition or answer seeking for Applicant any reorganization, arrangement, composition, readjustment, liquidation, dissolution or similar relief under any present or future statute, law or regulation relating to creditors’ rights;
(j)
within sixty days after the commencement of an action against Applicant seeking any reorganization, arrangement, composition, readjustment, liquidation, dissolution or similar relief under any present or future statute, law or regulation, such action has not been dismissed or all orders or proceedings thereunder affecting Applicant’s operations or business stayed;
(k)
any actual or threatened seizure, vesting or intervention by or under authority of a government by which Applicant’s management is displaced or its authority or control of its business is curtailed;
(l)
the attachment or restraint of any funds or other property which may be in, or come into, Issuer’s possession or control or of any third party acting on Issuer’s behalf or for Applicant’s account or benefit, or the issuance of any order of any court or other legal process against the same;
(m)
any event causing a Material Adverse Effect occurs;
(n)
Applicant consolidates or merges with or into any other entity, or transfers its property as an entirety or substantially as an entirety, unless (i) the entity (whether Applicant or another entity) formed by or surviving any such consolidation or merger, or to which such transfer shall have been made, shall not be in default under any of the terms, covenants and conditions of this Agreement, (ii) the entity (if other than Applicant) formed by or surviving any such consolidation or merger, or to which such transfer shall have been made, shall be a single (x) corporation or limited liability company organized under the laws of the United States of America or any State thereof or the District of Columbia or (y) sociedad anónima or sociedad limitada organized under the laws of the Kingdom of Spain, and (iii) the entity (if other than Applicant) formed by or surviving any such consolidation or merger, or to which such transfer shall have been made, shall have assumed in writing the payment of

17


all of Obligations under this Agreement and performance of all of the terms, covenants and conditions of this Agreement;
(o)
a Change of Control shall have occurred; or
(p)
Parent or Brookfield Asset Management Inc. fails to (i) perform its obligations under the Backstop Agreements to which it is a party with respect to the Applicant’s obligations under Section 16(iii)(k) of this Agreement or (ii) perform or observe any other term or covenant of any Facility Document to which it is a party in any material respect and such failure shall not have been remedied or waived within three (3) Business Days;
then the drawn and undrawn amount of each Credit as well as any other Obligations hereunder, whether or not matured or contingent, shall, at Issuer’s option, become due and payable immediately without presentment, demand, protest or notice of any kind, all of which are hereby expressly waived by Applicant; provided, however, that upon the occurrence of any Event of Default described in (i) or (j) above, the face amount of each Credit as well as all other Obligations hereunder, whether or not matured or contingent, shall automatically become due and payable without presentment, demand, protest or notice of any kind, all of which Applicant hereby expressly waives. In furtherance, and not in limitation, of the foregoing, upon the occurrence of any Event of Default Applicant shall, upon Issuer’s written demand, deposit U.S. Dollars in an amount equal to the U.S. Dollar Equivalent of the entire amount which has not been drawn under any Credit into a special cash collateral account, designated by Issuer and over which Issuer shall have exclusive right of withdrawal, which shall be charged to reimburse Issuer for amounts paid by Issuer and drawn under any Credit. Furthermore, in the case of an Event of Default specified in (a), Issuer may, in Issuer’s discretion, setoff amounts due and payable to Issuer under this Agreement or any individual Credit by any available funds then held by Issuer for Applicant’s account. For the avoidance of doubt, Issuer’s rights under this section are cumulative and in addition to other rights and remedies which Applicant may have under this Agreement or under applicable law.
9.    [RESERVED]
10.    Waiver of Rights; Amendments. No delay on Issuer’s part in the exercise of any right or remedy shall operate as a waiver thereof, and no single or partial exercise by Issuer of any right or remedy shall preclude other or further exercise thereof or the exercise of any other right or remedy. Issuer shall not be deemed to have waived any of Issuer’s rights hereunder unless Issuer or Issuer’s duly authorized agent shall have signed such waiver in writing. No such waiver, unless expressly stated therein, shall be effective as to any transaction which occurs subsequent to the date of such waiver, or as to any continuance of a breach after such waiver. This Agreement shall not be altered, modified, or amended without the prior written consent of the parties hereto.

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11.    Extensions, Increases and Modifications. Issuer shall have no obligation to issue, amend, renew, extend or replace any Credit hereunder or any Bank Guarantee. Each request Applicant makes for a Credit or any amendment, renewal or extension thereof shall be reviewed by Issuer on a case-by-case basis and the decision to issue, amend, renew or extend any such Credit shall be made by Issuer in Issuer’s sole discretion. In the event of any extension of the maturity or time for presentation of Drafts or documents, or any other modification of the terms of any Credit, at Applicant’s request or in the event of any increase in the amount of any Credit at Applicant’s request, this Agreement shall be binding upon Applicant with regard to such Credit so increased or otherwise modified, to Drafts, documents, and property covered thereby, and to any action taken by Issuer or any of Issuer’s correspondents in accordance with such extension, increase or other modification.
12.    No Liability for Certain Actions; Independence.
(a)
Without limiting any other provision of this Agreement, Applicant agrees that Issuer and Aval Provider and their respective branches, affiliates and correspondents shall not be liable or responsible in any respect for, and Applicant’s reimbursement obligations hereunder shall not be affected by, (a) the use which may be made of any Credit or Bank Guarantee or for any act of or omissions of the beneficiaries under any Credit or Bank Guarantee; (b) the validity, sufficiency, or genuineness of any instructions, oral or written, or any documents which Issuer has determined in good faith to comply on their face with the terms of the relevant Credit or Bank Guarantee, even if such documents should in fact prove to be in any or all respects invalid, fraudulent, or forged; (c) errors, omissions, interruptions or delays in transmission or delivery of any messages or advices from Applicant or the beneficiaries, however sent and whether or not in code or cipher; (d) Issuer’s refusal to pay or honor Drafts drawn under any Credit (or Aval Provider’s refusal to pay or honor draft requests under any Bank Guarantee) because of any applicable law, decree or edict of any Governmental Authority now or hereafter in force; (e) the identity or authority of any signer or the form, accuracy, genuineness, falsification or legal effect of any draft, certificate or other document appearing on its face (i) substantially to comply with the terms and conditions of a Credit or Bank Guarantee, (ii) to be signed or presented by or issued to any successor of the beneficiary or any other Person in whose name a Credit or Bank Guarantee requires or authorizes that any draft, certificate or other document be signed, presented or issued, including any administrator, executor, personal representative, trustee in bankruptcy, debtor in possession, liquidator, receiver, or successor by merger or consolidation, or any other Person purporting to act as the representative of or in place of any of the foregoing, or (iii) to have been signed, presented or issued after a change of name of the beneficiary, (f) any requirement stated in a Credit or Bank Guarantee that any draft, certificate or other document be presented at a particular hour or place and any

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discrepancies that do not reduce the value of the beneficiary’s performance to Applicant in any transaction underlying any Credit or Bank Guarantee, (g) Issuer’s or Aval Provider’s acceptance as a “draft” of any written or electronic demand or other request for payment under any Credit or Bank Guarantee, even if such demand or other request is not in the form of a negotiable instrument, (h) the effectiveness or suitability of any Credit or Bank Guarantee for Applicant’s purpose, (i) any consequential or special damages, or for any damages resulting from any change in the value of any foreign currency, services or goods or other property covered by any Credit or Bank Guarantee, (j) Issuer’s assertion or waiver of application of any UCP or ISP (in each case, as defined below) article primarily benefiting bank issuers, (k) Issuer’s or Aval Provider’s honor of a previously dishonored presentation under any Credit or Bank Guarantee, whether pursuant to court order, to settle or compromise any claim that it wrongfully dishonored or otherwise, and Issuer and Aval Provider shall be entitled to reimbursement to the same extent as if it had initially honored said presentation plus reimbursement of any interest paid by it, (l) Issuer’s or Aval Provider’s disregard of any non-documentary conditions stated in any Credit or Bank Guarantee and (m) Issuer’s or Aval Provider’s payment to any nominated bank (as such term is defined in the UCP or nominated person (as such term is defined in the ISP) (in either case as designated or permitted by the terms of any Credit or Bank Guarantee) claiming that it rightfully honored under the laws, customs or practice of the place where it is located, except to the extent that any such item, action or omission in each of (a) through (m) above is found by a court of competent jurisdiction (in a final and non-appealable judgment) to have resulted from the willful misconduct or gross negligence of Issuer, Aval Provider or their respective branches, affiliates and correspondents. None of the foregoing shall affect, impair or prevent the vesting of any of Issuer’s rights or powers hereunder or Applicant’s reimbursement obligations hereunder except to the extent that any of the foregoing is found by a court of competent jurisdiction (in a final and non-appealable judgment) to have resulted from the willful misconduct or gross negligence of Issuer, Aval Provider or their respective branches, affiliates and correspondents. Issuer, Aval Provider and their respective branches, affiliates and correspondents will not be regarded as the drafter of any Credit or Bank Guarantee regardless of any assistance that Issuer may, in Issuer’s discretion, provide to Applicant in preparing the text of any Credit or Bank Guarantee or amendments thereto. For the avoidance of doubt, Issuer and Aval provider are authorized (but not obligated) to accept and rely on instructions received by facsimile transmission or e-mail that Issuer or Aval Provider believes in good faith to have been given by a Person authorized to give instructions on Applicant’s behalf. Issuer and Aval provider shall incur no liability to Applicant or any other Person as a result of any act or omission on Issuer’s or Aval Provider’s

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part in accordance with instructions on which Issuer or Aval Provider is authorized to rely, nor for any failure or refusal on Issuer’s or Aval Provider’s part to accept instructions by facsimile transmission or e-mail that are not confirmed or authenticated to Issuer’s or Aval Provider’s satisfaction.
(b)
Applicant acknowledges that Issuer’s rights and obligations under a Credit and Aval Provider’s rights and obligations under a Bank Guarantee are independent of the existence, performance or nonperformance of any contract or arrangement underlying a Credit or Bank Guarantee, including contracts or arrangements between Issuer and Applicant and between Applicant and the beneficiary of a Credit or Bank Guarantee. Issuer and Aval Provider shall have no duty to notify Applicant of Issuer’s or Aval Provider’s receipt of a demand or a Draft, certificate or other document presented under a Credit or bank Guarantee or of Issuer’s or Aval Provider’s decision to honor such demand. Issuer and Aval Provider may, without incurring any liability to Applicant or impairing Issuer’s entitlement to reimbursement under this Agreement, honor a demand under a Credit or Bank Guarantee despite notice from Applicant of, and without any duty to inquire into, any defense to payment or any adverse claims or other rights against the beneficiary of a Credit or Bank Guarantee or any other Person. Issuer and Aval Provider shall have no duty to request or require the presentation of any document, including any default certificate, not required to be presented under the terms and conditions of a Credit or Bank Guarantee. Issuer and Aval Provider shall have no duty to seek any waiver of discrepancies from Applicant, nor any duty to grant any waiver of discrepancies that Applicant approves or requests.
13.    No Violation of Law. Applicant hereby represents and warrants that none of the execution, delivery or performance of this Agreement or any other Facility Document by Applicant or Parent, nor the request for any issuance of, or amendment to, a Credit or Bank Guarantee will violate or contravene any applicable law or regulation. If Applicant’s obligations under this Agreement should be terminated or revoked by operation of law, Applicant will indemnify and save Issuer harmless from any loss (including reasonable out of pocket expenses) that may be incurred by Issuer in acting hereunder prior to such termination or revocation and the maturity or payment of all outstanding Credits.
14.    Practices for Documentary Credits. Each Credit shall be subject to, and the performance by Issuer thereunder shall be governed by, the Uniform Customs and Practice for Documentary Credits (2007 Revision), International Chamber of Commerce, Publication No. 600 or any subsequent revision thereof adopted from time to time by the International Chamber of Commerce (the “UCP”) unless such Credit is a standby letter of credit that expressly states that it is subject to the International Standby Practices, International Chamber of Commerce Publication No. 590 or

21


any subsequent amendment thereto or subsequent revision thereof (the “ISP”, and together with the UCP, the “ICC Rules”). Issuer’s privileges, rights and remedies under such ICC Rules shall be in addition to, and not in limitation of, Issuer’s privileges, rights and remedies expressly provided for herein. The UCP and the ISP shall serve, in the absence of proof to the contrary, as evidence of general banking usage with respect to the subject matter thereof.
Furthermore, Applicant agrees that for matters not addressed by the chosen ICC Rule, each Credit shall be subject to and governed by the laws of the State of New York and applicable United States Federal laws. If, at Applicant’s request, a Credit expressly chooses a state or country law other than New York State law and United States Federal law or is silent with respect to the choice of an ICC Rule or a governing law, Issuer shall not be liable for any payment, cost, expense or loss resulting from any action or inaction taken by Issuer if such action or inaction is or would be justified under an ICC Rule, New York law, applicable United States Federal law or the law governing such Credit.
15.    Obligations Absolute. Applicant’s Obligations under this Agreement are absolute, unconditional and irrevocable, and shall be paid (or performed, as the case may be) strictly in accordance with the terms of this Agreement, under all circumstances whatsoever, including the following circumstances: (a) the existence of any claim, set-off, defense or other right which Applicant may have at any time against Issuer, Aval Provider or any Person, whether in connection with this Agreement, any Credit, any Bank Guarantee or any unrelated transaction, (b) any draft, statement, certificate or any other document presented under any Credit or Bank Guarantee proving to be forged, fraudulent, incorrect, insufficient or invalid in any respect or any statement therein being untrue or inaccurate in any respect whatsoever, (c) any lack of validity or enforceability of this Agreement, a Credit, a Bank Guarantee or any other agreement, application, amendment, guaranty, document, or instrument relating thereto, (d) any change in the time, manner or place of payment of or in any other term of all or any of Applicant’s Obligations hereunder or the obligations of any Person that guarantees or otherwise provides support for any of Applicant’s Obligations hereunder, (e) any exchange, release or non-perfection of any collateral or release or amendment or waiver of or consent to depart from the terms of any guarantee or security agreement, for all or any of Applicant’s Obligations hereunder, (f) the issuance of a Credit (or any amendment thereto) or Bank Guarantee (or any amendment thereto) in a form other than substantially as requested by Applicant, unless Issuer receives written notice from Applicant of such error within three (3) Business Days after Applicant shall have received a copy of such Credit (or amendment thereto) or Bank Guarantee (or amendment thereto), (g) Issuer’s decision not to issue an amendment to a Credit or request an amendment to a Bank Guarantee as requested by Applicant, (h) payment by Issuer under a Credit or Aval Provider under a Bank Guarantee against presentation of a draft or other document that does not comply with the terms and conditions of a Creditor Bank Guarantee (as applicable) unless Issuer receives written notice from Applicant of such discrepancy within three (3) Business Days following Applicant’s receipt of such draft or other document, and (i) any action or inaction taken or suffered by Issuer, Aval Provider or any of their respective affiliates or

22


correspondents in connection with a Credit or Bank Guarantee or any relevant draft, certificate or other document, if taken in Good Faith (as defined in Article 5 of the New York Uniform Commercial Code) and in conformity with applicable New York, United States or non-United States laws, regulations or letter of credit customs and practice.
16.    Representations, Warranties and Covenants
(i)        Representations and Warranties.
Applicant represents and warrants to Issuer that:
(a)
Each Credit Party is organized, validly existing and in good standing under the laws of its applicable jurisdiction of organization. The Applicant (a) has the power and authority, and the legal right, to conduct the business in which it is currently engaged; (b) is duly qualified as a foreign corporation and in good standing under the laws of each jurisdiction where the conduct of its business requires such qualification; and (c) is in compliance with all material requirements of applicable law.
(b)
Each Credit Party has the power and authority, and the legal right, to make, deliver and perform the Facility Documents to which it is a party and, with respect to the Applicant, to obtain extensions of credit hereunder. Each Credit Party has taken all necessary organizational action to authorize the execution, delivery and performance of the Facility Documents to which it or the Applicant is a party and to authorize the extensions of credit to the Applicant on the terms and conditions of this Agreement. No consent or authorization of, filing with, notice to or other act by or in respect of, any Governmental Authority or any other Person is required in connection with the transactions contemplated hereby and the extensions of credit hereunder or with the execution, delivery, performance, validity or enforceability of this Agreement of the other Facility Documents. Each Credit Party has duly executed and delivered each Facility Document to which it is a party. This Agreement constitutes, and each other Facility Document upon execution will constitute, a legal, valid and binding obligation of each Credit Party party thereto, enforceable against each such Credit Party in accordance with its terms, except as enforceability may be limited by applicable bankruptcy, insolvency, reorganization, moratorium or similar laws affecting the enforcement of creditors’ rights generally and by general equitable principles (whether enforcement is sought by proceedings in equity or at law).
(c)
The execution, delivery and performance of this Agreement and the issuance of the Credit will not violate any law, any provision of the certificate of formation (escritura de constitución), articles of association (estatutos) or other organizational documents of Applicant or violate any contractual obligation of any Credit Party, and will not

23


result in, or require, the creation or imposition of any lien on any Credit Party’s respective properties or revenues pursuant to any such requirement of law or any such contractual obligation except, in each case (other than the Backstop Agreements and Cobra Irrevocable Agreement) where such violations could not (individually or in the aggregate) reasonably be expected to have a Material Adverse Effect.
(d)
No default or event of default exists or, after giving effect to any Draw, will exist, under the Cobra Irrevocable Agreement, any Backstop Agreement or any other Facility Document.
(e)
No Default or Event of Default exists or, after giving effect to any Draw, will exist, under this Agreement.
(f)
No extensions of credit hereunder, will be used for “buying” or “carrying” any “margin stock” within the respective meanings of each of the quoted terms under Regulation U as now and from time to time hereafter in effect or for any purpose that violates the provisions of the regulations of the Board.
(g)
Neither Parent nor any of its subsidiaries is (i) subject to regulation under the Investment Company Act of 1940 (as amended) or (ii) a “registered investment company” or a company “controlled” by a “registered investment company” or a “principal underwriter” of a “registered investment company” as such terms are defined in the Investment Company Act of 1940 (as amended).
(h)
On the Effective Date, Parent and its subsidiaries are, on a consolidated basis, and after giving effect to the extensions of credit made hereunder will be, solvent.
(i)
(i) The full legal name of the Applicant is TERP Spanish HoldCo, S.L.; and (ii) the Applicant is a sociedad limitada organized under the laws of the Kingdom of Spain.
(j)
The Applicant (a) has not conducted any business other than the business contemplated by the Articles of Association and (b) has no outstanding contractual obligations other than those (i) set forth in the Facility Documents or (ii) allowed pursuant to its Articles of Association and the Facility Documents and related to the incorporation and ongoing corporate matters of the Applicant, its acquisition by Norrington or the Offer.
(k)
There are no pending, nor has any Credit Party received written notice regarding, threatened actions or proceedings of any kind, including actions or proceedings of or before any Governmental Authority, to which a Credit Party or any subsidiary or affiliate thereof that is an Account Party is a party or is subject, or by which any of

24


its respective properties are bound that would reasonably be expected to result in a Material Adverse Effect.
(l)
Each financial statement of the Applicant, delivered to Issuer, has been prepared in conformity with Spanish GAAP and fairly presents, in all material respects, the financial position of the Applicant described in such financial statements as at the respective dates thereof and the results of operations and the changes in cash flows of the Applicant described therein for each of the periods then ended except as otherwise noted therein and subject, in the case of any such unaudited financial statements, to changes resulting from audit and normal year-end adjustments. As of December 31, 2017, the Applicant did not have any material Indebtedness or material guarantees other than as referenced, reflected or provided for in such audited financial statements (or in the notes thereto) in accordance with customary auditing standards.
(m)
All written information (other than any “forward looking statements”) (the “Information”) concerning the Credit Parties and the transactions contemplated hereby prepared by, or as directed by, the Credit Parties or any of their Affiliates and made available to Issuer on or prior to the Effective Date in connection with the transactions contemplated hereby, when taken as a whole, was true and correct in all material respects as of the date such Information was furnished to the Issuer and as of the Effective Date and (as of the date such Information was furnished to the Issuer and as of the Effective Date) did not contain any untrue statement of a material fact or omit to state a material fact necessary in order to make the statements contained therein (taken as a whole) not materially misleading in light of the circumstances under which such statements were made.
(n)
The Applicant (a) has timely filed or caused to be timely filed all material tax returns required to have been filed by them and (b) have timely paid or caused to be paid all material taxes due and payable by them, except any taxes or assessments that are being contested in good faith by appropriate proceedings for which appropriate reserves have been established in accordance with Spanish GAAP. No tax liens have been filed with respect to the assets of the Applicant.
(o)
None of the Credit Parties nor any of their respective properties or assets is in violation of (nor will the continued operation of its properties and assets as currently conducted violate) (i) its organizational documents or (ii) any currently applicable laws, except (solely with respect to this clause (ii)) any violation or non-compliance that would not reasonably be expected to result in a Material Adverse Effect. None of the Credit Parties are in default under or with respect to any of their respective material

25


contractual obligations in any respect that would reasonably be expected to result in a Material Adverse Effect.
(p)
None of the Credit Parties has engaged in any unfair labor practice that would reasonably be expected, individually or in the aggregate, to result in a Material Adverse Effect.
(q)
The Applicant does not have any employees in the United States and is not subject to the jurisdiction of or any regulations related to the Employee Retirement Income Security Act of 1974, as amended.
(r)
The activities of the Credit Parties and each subsidiary thereof are in compliance with all, and have not violated any, environmental laws, other than as would not reasonably be expected to, individually or in the aggregate, result in a Material Adverse Effect.
(s)
None of the Credit Parties or any subsidiary thereof has received any written notice that any aspect of the business or the operations or facilities (whether owned or leased) of any Credit Party is in violation of, or in noncompliance with, any environmental law or is subject to liability under any environmental law, that would reasonably be expected to, individually or in the aggregate, result in a Material Adverse Effect.
(t)
Parent owns and controls, directly or indirectly, more than a majority of the voting power and economic interests in the Applicant. All of the issued and outstanding membership interests of the Applicant have been duly authorized and issued and are fully paid and non-assessable. For purposes of this paragraph, “control” of a Person means the power, directly or indirectly, either to (a) vote the specified percentage of the securities having ordinary voting power for the election of directors (or persons performing similar functions) of such Person or (b) direct or cause the direction of the management and policies of such Person, whether by contract or otherwise.
(u)
No member of the Group, nor any of Applicant’s or their respective joint ventures, directors, officers or employees nor, to Applicant’s knowledge, any Persons acting on any of their behalf (a) is a Restricted Party; or (b) has received notice of or is aware of any claim, action, suit, proceeding or investigation against it with respect to Sanctions by any Sanctions Authority.
(v)
The operations of each member of the Group are and have been conducted at all times in compliance with all applicable Anti-Money Laundering Laws and Anti-Corruption Laws and no action, suit or proceeding by or before any Governmental Authority or any arbitrator involving a member of the Group with respect to Anti-

26


Money Laundering Laws and/or Anti-Corruption Laws is pending and no such actions, suits or proceedings are threatened or contemplated.
Each request by Applicant for an amendment to this Agreement or for the issuance of a Credit or for any amendment to a Credit and each such amendment or issuance or any Draw shall constitute Applicant’s representation and warranty that the foregoing statements are true and correct as if made on the date of such request.
(ii)        Information Covenants.
Applicant shall furnish to Issuer:
(a)
as soon as practicable and in any event within sixty (60) days after the end of each quarterly period in each fiscal year, which is not the end of a fiscal year, Parent’s unaudited consolidated profit and loss statements and reconciliation of retained earnings statements for the period from the beginning of the current fiscal year to the end of such quarterly period, and Parent’s consolidated balance sheet as at the end of such quarterly period, setting forth in each case in comparative form corresponding consolidated figures from the corresponding period in the immediately preceding fiscal year, all in reasonable detail and prepared in accordance with U.S. GAAP and certified by Parent’s chief financial officer, treasurer, assistant treasurer or controller (“Responsible Officer”) subject to changes resulting from year-end adjustments that such financial statements fairly present in all material respects the financial condition and results of operations for such period; provided that the filing by Parent of its quarterly reports and consolidated financial statements on either the U.S. Securities and Exchange Commission’s EDGAR filing system or a publicly accessible website will be deemed to satisfy the obligations of Applicant under this Section 16(ii)(a);
(b)
promptly upon obtaining knowledge of the occurrence of any Event of Default pursuant to Section 8 (Default) or any event which with notice or lapse of time or both would constitute an Event of Default pursuant to Section 8 (Default), notify Issuer thereof in writing, specifying the nature thereof and the action Applicant proposes to take with respect thereto;
(c)
prompt written notice of any event or development that Applicant believes would reasonably be expected to have a Material Adverse Effect;
(d)
with reasonable promptness, any other financial data relating to the performance of this Agreement and Applicant’s affairs that Issuer may from time to time reasonably request; and

27


(e)
by the last Business Day of each month, provide a Responsible Officer’s certificate certifying the available amounts to be drawn under each of the Backstop Agreements, and that no default or event of default under such Backstop Agreement exists and that, to the knowledge of such Responsible Officer, such amounts are available to be drawn.
(iii)        Affirmative Covenants.
Applicant will:
(a)
comply with all New York, United States and non-United States laws, regulations and rules (including all tax, Anti-Money Laundering Laws, Anti-Corruption Laws, Sanctions, foreign exchange and foreign assets control regulations and other trade-related regulations) and letter of credit customs and practice now or later applicable to a Credit, transactions related to a Credit, or Applicant’s execution, delivery and performance under this Agreement and deliver to Issuer, upon reasonable request, satisfactory evidence of such compliance;
(b)
conduct the Offer at all times in compliance with the terms and conditions of the Offer Documents;
(c)
permit Issuer to inspect Applicant’s books and records on reasonable notice;
(d)
preserve and maintain Applicant’s existence, rights, franchises and business operations;
(e)
except as otherwise expressly permitted under the Facility Documents, (i) maintain and preserve its existence as a sociedad limitada and all material rights, privileges and franchises necessary or desirable in the normal conduct of its business and (ii) perform (to the extent not excused by force majeure events or the non-performance of the other party), all of its material contractual obligations under the Facility Documents, the Cobra Irrevocable Agreement and all other agreements and contracts by which it is bound;
(f)
maintain adequate books, accounts and records and prepare all financial statements required under the Facility Documents in accordance with Spanish GAAP and in compliance with the regulations of any Governmental Authority having jurisdiction thereof, and permit each of the employees or agents of the Issuer during business hours and upon reasonable prior notice to inspect all Applicant’s and Applicant’s subsidiaries’ properties, to examine or audit all of Applicant’s books, accounts and records and make copies and memoranda thereof;

28


(g)
file, as and when due, all tax returns and shall pay, or cause to be paid, as and when due and prior to delinquency, all taxes, assessments and governmental charges of any kind that may at any time be lawfully assessed or levied against or with respect to Applicant; provided, that Applicant may contest in good faith any such taxes, assessments and other charges and, in such event, may permit the taxes, assessments or other charges so contested to remain unpaid during any period, including appeals, when Applicant is in good faith contesting the same, so long as (i) reasonable reserves have been established in an amount sufficient to pay any such taxes, assessments or other charges, accrued interest thereon and potential penalties or other costs relating thereto, or other adequate provision for the payment thereof shall have been made; (ii) enforcement of the contested tax, assessment or other charge is effectively stayed for the entire duration of such contest; and (iii) any tax, assessment or other charge determined to be due, together with any interest or penalties thereon, is paid when due after resolution of such contest;
(h)
at its expense, within such time as may be required by applicable law comply, or cause compliance in all material respects, with all legal requirements applicable to Applicant, except that Applicant may, at its expense, contest by appropriate proceedings conducted in good faith the validity or application of any such legal requirements provided that (i) none of Issuer, Aval Provider or any Credit Party would be subject to any criminal liability for failure to comply therewith; and (ii) all proceedings to enforce such legal requirements against the Issuer, Aval Provider, or any Credit Party, shall have been duly and effectively stayed during the entire pendency of such contest;
(i)
cause to be maintained at all times, and provide evidence reasonably acceptable to Issuer that availability exists, minimum availability under Backstop Agreements as follows: (1) no less than US$400,000,000 under the Revolver and (2) no less than US$500,000,000 under the Sponsor Line;
(j)
if at any time after the Effective Date, the Applicant agrees to limitations on Indebtedness, limitations on liens or financial covenants, in the documentation evidencing any other Indebtedness of the Applicant, any of which are more stringent or restrictive than the limitations or financial covenants in this Agreement, or, with respect to the Santander Facility, any covenants more favorable to the lender under such facility, then, at Issuer’s option (which may be exercised at any time), this Agreement will be deemed automatically amended so that Issuer also shall benefit from such more stringent or restrictive limitations and financial covenants, or with respect to the Santander Facility, any such covenants, such that a breach of such more stringent or restrictive limitations and financial covenants or other covenants

29


shall constitute a breach of this Section 16 (Representations, Warranties and Covenants), and this Agreement regardless of any waiver or forbearance granted by the creditors of such other Indebtedness or termination or repayment of any such other Indebtedness. The Applicant agrees to promptly inform Issuer of any such other Indebtedness and to furnish to Issuer a copy of the documentation containing such more stringent or restrictive limitations and financial covenants.  The Applicant further agrees to enter into such amendments to this Agreement as reasonably requested by Issuer to conform this Agreement as contemplated by the first sentence of this Section 16(iii)(j) (it being acknowledged and agreed that the failure to enter into any such amendment shall not limit the effectiveness of the first sentence of this Section 16(iii)(j);
(k)
in the event that that (x) Issuer shall demand that Applicant fund any cash collateral deposit pursuant to the last paragraph of Section 8 (Defaults) or (y) any Draft is made on a Credit,
(i)
promptly (and in any event not more than (x) three (3) Business Days following such demand or Draft with respect to any drawing described in sub-clause (A) immediately below or (y) forty-five (45) days following such demand or Draft with respect to any issuance described sub-clause (B) immediately below) cause Parent to take (and/or cause its applicable subsidiaries (including TPO) (as the case may be) to take) the following actions to the extent required to ensure that the Applicant has immediately available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding Draft (together with any other Obligations then payable) and any corresponding collateralization, reimbursement or other obligations due under the Santander Facility:
(A)    first, cause TPO to submit a request for and draw the maximum amount available to be drawn under the Revolver; and/or submit a request for and draw the maximum amount available to be drawn under the Sponsor Line; and
(B)    second, issue and sell new shares of Class A common stock in Parent for net proceeds in an amount not to exceed US$400 million; and
(ii)
promptly (and in any event not more than forty-five (45) days following the applicable demand or Draft), cause Parent to make or cause to be made (and/or cause its applicable subsidiaries (including TPO) (as the case may be) to make or cause to be made) equity contributions to Applicant (utilizing in whole or in part, in its sole discretion, an amount up to the net proceeds

30


resulting from such drawings and/or issuance) to the extent required to ensure that the Applicant has immediately available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding Draft (together with any other Obligations then payable) and any corresponding collateralization, reimbursement or other obligations due under the Santander Facility; provided that, notwithstanding the foregoing, in any event Applicant shall cause Parent to contribute or cause to be contributed (and/or cause its applicable subsidiaries (including TPO) (as the case may be) to contribute or cause to be contributed) the amounts required to be requested pursuant to Section 16(iii)(k)(i)(A) in an amount equal to the lesser of (x) US$900,000,000 and (y) the amount of any demanded cash collateral and (without duplication) outstanding Draft (together with any other Obligations then payable) to Applicant not more than eight (8) Business Days following the applicable demand or Draft; and
(l)
on or prior to the third (3rd) Business Day following the Effective Date, pay all fees due and payable pursuant to Section 3 (Payment for Services Rendered), together with all costs and expenses, including legal expenses, of the Issuer and Aval Provider and any fees payable pursuant to any Credit and Bank Guarantee issued on or prior to the third (3rd) Business Day following the Effective Date.
(iv)        Negative Covenant.
Applicant will not, and will not permit or authorize any of its subsidiaries to:
(a)
directly or indirectly, use, lend, make payments of, contribute or otherwise make available, all or any part of the proceeds of any Credit or other transaction(s) contemplated by this Agreement to fund any trade, business or other activities: (i) involving or for the benefit of any Restricted Party, or (ii) in any other manner that would reasonably be expected to result in any member of the Group or any Lender being in breach of Sanctions, Anti-Money Laundering Laws, and/or Anti-Corruption Laws (if and to the extent applicable to them) or becoming a Restricted Party;
(b)
enter into or become a party to any contracts or agreements not related to ownership of SAY or the transactions contemplated by the Facility Documents;
(c)
sell, assign, pledge or in whatever form dispose of or encumber any of the SAY shares acquired under the Offer until any amounts due by the Applicant under this Agreement and all of the Applicant’s Obligations hereunder have been fully satisfied;
(d)
liquidate, wind-up or dissolve, or sell or lease or otherwise transfer or dispose of all or any substantial part of its property, assets or business or combine, merge or

31


consolidate with or into any other entity, or change its legal form, or implement any material acquisition or purchase of assets from any Person;
(e)
except as provided in the Santander Facility or other Facility Documents, become liable as a surety, guarantor, accommodation endorser or otherwise, for or upon the obligation of any other Person or otherwise create, incur, assume or suffer to exist any contingent obligation;
(f)
except as provided in the Santander Facility, this Agreement or the other Facility Documents, incur, create, assume or permit to exist any Indebtedness or any lien on Applicant’s assets or properties;
(g)
execute a binding agreement to become a general or limited partner in any partnership, or a member in any limited liability company, sociedad de responsabilidad limitada, sociedad anónima, other company, or a joint venturer in any joint venture or acquire property, create and hold stock or other equity interests in any Person or form or acquire any subsidiaries, in each case (i) other than the Applicant and (ii) not related to ownership of SAY or the transactions contemplated by the Facility Documents;
(h)
cause, consent to, or permit any termination, amendment, modification, variance or waiver of timely compliance with any terms or conditions of the certificate of formation (escritura de constitución) or any other organizational documents of Applicant;
(i)
change its name or its jurisdiction of organization without written notice to the Issuer at least thirty days prior to such change, or change its fiscal year;
(j)
change the location of its chief executive office or principal place of business without written notice to the Issuer within thirty (30) days after such change;
(k)
modify or amend, waive or terminate in any manner adverse to the Issuer, any of the Backstop Agreements or the Cobra Irrevocable Agreement; or
(l)
modify or amend the Santander Facility without Issuer’s prior written consent.
17.    Effectiveness/Assignment. This Agreement shall become effective the Effective Date and shall be binding upon Applicant and Applicant’s successors and assigns. No assignment or other transfer of all or any of the rights of the undersigned hereunder, whether with regard to any property or otherwise, may be made without Issuer’s prior written consent.
18.    Waiver of Immunity. Applicant acknowledges that this Agreement is, and each Credit and Bank Guarantee will be, entered into for commercial purposes and, to the extent that Applicant now

32


or later acquires any immunity from jurisdiction of any court or from any legal process with respect to Applicant or Applicant’s property, Applicant now irrevocably waives Applicant’s immunity with respect to Applicant’s Obligations hereunder.
19.    Termination; Surviving Provisions.
If the Offer is withdrawn or cancelled, this Agreement and any Credits will be automatically cancelled on the earlier to occur of (x) the end of the L/C Commitment Period and (y) the date falling three months after such withdrawal or cancellation.
If, as at the date on which settlement of the Offer occurs, the conditions set forth in Article 47 of RD 1066/2007 for the exercise by the Applicant and SAY shareholders of the squeeze-out and sell-out respective rights are satisfied, (a) any Credits will not be cancelled in full and (b) any cancellation in part will be made following prior consultation of the Issuer and Applicant with CMNV and subject to the CNMV’s instructions thereto.
Restrictive provisions in this Agreement, such as indemnity, tax, immunity and jurisdiction provisions shall survive termination of this Agreement, expiration of any Credit, and payment of Applicant’s Obligations hereunder. If any Credit is issued in favor of any bank, Natixis branch or other entity in support of an undertaking issued by such bank, branch or entity on Applicant’s behalf or request, Applicant shall remain liable under this Agreement (even after expiry of such Credit) for amounts paid and expenses incurred by Issuer with respect to such Credit or such undertaking until such time as Issuer or such other bank, branch or entity shall have no further liability, under applicable law, in connection with such undertaking.
20.    Notices. Except as expressly provided to the contrary herein, any communication, notice or demand to be given hereunder shall be duly given if delivered or mailed by certified or registered mail or sent by, fax or email as follows:

33


If to Applicant, at:
TERP Spanish HoldCo, S.L.
 
99 Bishopsgate, London, EC2M 3XD
 
Attention: Ms. Emmanuelle Rouchel
e-mail: ####@brookfield.com

and

TERP Spanish HoldCo, S.L.
21 calle Serrano, 2nd floor, 28001, Madrid, Spain
Attention: Mr. Richardo Arias
e-mail: ####@brookfield.com

With a copy to:

TerraForm Power, Inc.
7550 Wisconsin Avenue, 9th Floor.
Bethesda, Maryland, 20814
Attention: General Counsel
e-mail: ####@brookfield.com

If to Issuer, at:
Natixis, New York Branch
 
1251 Avenue of the Americas
 
New York, NY 10020
 
Attention: General Counsel
 
fax: 212-891-1922
 
e-mail: legal.notices@us.natixis.com

Applicant agrees that Issuer may act upon email or facsimile instructions which are received by Issuer from Persons purporting to be, or which instructions appear to be, authorized by Applicant. Applicant further agrees to indemnify and hold Issuer harmless from any claims by virtue of Issuer acting upon such email or facsimile instructions as such instructions were understood by Issuer, except to the extent such claims relate to Issuer’s gross negligence or willful misconduct. Issuer shall not be liable for any errors in transmission or the illegibility of any emailed or telecopied documents. In the event Applicant sends Issuer a manually signed confirmation of previously sent email, or facsimile instructions, Issuer shall have no duty to compare it against the previous instructions received by Issuer nor shall Issuer have any responsibility should the contents of the written confirmation differ from the email or facsimile instructions acted upon by Issuer.
21.    Interpretation. The parties acknowledge and agree that (a) each party and its counsel have reviewed the terms and conditions of this Agreement and have contributed to the revision of same, (b) the normal rule of construction which holds that any ambiguities are resolved against the drafting party, shall not be employed in the interpretation of this Agreement, (c) the terms and provisions

34


of this Agreement shall be constructed fairly as to both parties hereto and not in favor of or against any party, regardless of which party was generally responsible for the preparation of this Agreement, (d) the term “including” means “including without limitation, as used in this Agreement, (e) if any provision of this Agreement is held illegal or unenforceable, the validity of the remaining provisions shall not be affected, (f) headings are included only for convenience and are not interpretive, (g) this Agreement constitutes the entire agreement between the parties concerning Issuer’s issuance of one or more Credits for Applicant’s account and supersedes all prior agreements governing such issuance, (h) Applicant may submit an executed Application for a Credit in original form, via fax, email attachment or other electronic means and Applicant will be bound by any instructions so given, (i) delivery of a signed signature page to this Agreement by facsimile transmission or email attachment shall be effective as, and shall constitute physical delivery of, a signed original counterpart of this Agreement, (j) if this Agreement is signed by two or more persons or entities, (i) each such person or entity shall be deemed an “Applicant” hereunder, (ii) each Applicant shall be jointly and severally liable for all the Obligations hereunder, and (iii) notices from Issuer in connection with this Agreement or the Credit to either Applicant and notices from, or the consent of, either Applicant in connection with this Agreement or the Credit shall be sufficient to bind all Applicants; (k) all references herein and in any other Facility Document to any fees, Credits, Bank Guarantees, Stated Amounts and other obligations and amounts shall be denominated in U.S. Dollars, unless expressly provided otherwise; (l) the Applicant and Parent shall deliver financial statements and calculate and perform financial and other covenants in U.S. Dollars; and (m) notwithstanding anything to the contrary herein or in any other Facility Documents, even if an obligation is funded and expressly denominated in Euros, the Applicant and Parent shall repay the U.S. Dollar Equivalent of such obligation in U.S. Dollars.
22.    Multiple Role Disclosure. Issuer and Issuer’s affiliates offer a wide range of financial services. Such services are provided internationally to a wide range of customers, some of whom may be Applicant’s counterparties or competitors. Applicant acknowledges and accepts that Issuer and Issuer’s affiliates may perform more than one role in relation to a Credit, including advising a Credit, notwithstanding the selection by Applicant of an additional or alternative advising bank.
23.    Governing Law and Jurisdiction. This Agreement shall be governed and construed in accordance with the laws of the State of New York. For the purposes of any proceeding, action or suit involving this Agreement, each party hereto hereby expressly submits to the jurisdiction of any court of record of New York State or the United States located in the City of New York, Borough of Manhattan, and agrees that any order, process or other paper may be served upon either party within or without such court’s jurisdiction by mailing a copy thereof to the affected party at its address (that with respect to Issuer, shall be Issuer’s address shown on the first page of this Agreement, and with respect to Applicant, shall be Applicant’s address shown below). Each party waives any claim that such proceeding, action or suit has been brought in an inconvenient forum. EACH PARTY WAIVES TRIAL BY JURY.

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24.    Service of Process. Applicant agrees that any service of process or other notice of legal process may be served upon it by mail or hand delivery if sent to:
 
TerraForm Power, Inc.
7550 Wisconsin Avenue, 9th Floor.
Bethesda, Maryland, 20814
Attention: General Counsel

which Applicant now confirms Applicant has designated as its authorized agent for service of process with respect to the courts located in the State of New York in relation to each Credit and this Agreement. Applicant agrees that service of all process in any such proceeding in any such court may be made by registered or certified mail, return receipt requested, to such address and agrees that service as provided above is sufficient to confer personal jurisdiction over Applicant in any such proceeding in any such court, and otherwise constitutes effective and binding service in every respect.
In furtherance, and not in limitation of the foregoing, Applicant agrees that nothing in this Agreement shall affect Issuer’s right to serve process in any other manner permitted by law or to commence legal proceedings or otherwise proceed against Applicant in any other jurisdiction. Furthermore, Applicant agrees that final judgment against Applicant in any action or proceeding shall be enforceable in any other jurisdiction within or outside the United States by suit on the judgment, a certified copy of which shall be conclusive evidence of the judgment.
25.    Patriot Act. Applicant acknowledges that pursuant to the requirements of the USA Patriot Act (Title III of Pub. L. 107-56 (signed into law October 26, 2001)) (the “Patriot Act”), Issuer is required to obtain, verify and record information that identifies Applicant, which information includes Applicant’s name and address and other information that will allow Issuer to identify Applicant in accordance with the Patriot Act.
26.    Bail-In Recognition. Notwithstanding anything to the contrary in this Agreement or any Credit or in any other agreement, arrangement or understanding among the parties hereto, each party hereto acknowledges that any liability of any EEA Financial Institution arising under this Agreement or any Credit, except to the extent such liability is excluded under the Bail-In Legislation from the scope of any Bail-In Action, may be subject to the write-down and conversion powers of an EEA Resolution Authority and agrees and consents to, and acknowledges and agrees to be bound by:
(a)
the application of any Write-Down and Conversion Powers by an EEA Resolution Authority to any such liabilities arising hereunder which may be payable to it by any party hereto that is an EEA Financial Institution; and

36


(b)
the effects of any Bail-in Action on any such liability, including, if applicable:
(i)
a reduction in full or in part or cancellation of any such liability including without limitation a reduction in any accrued or unpaid interest in respect of such liability;
(ii)
a conversion of all, or a portion of, such liability into shares or other instruments of ownership in such EEA Financial Institution, its parent undertaking, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect to any such liability under this Agreement or any Credit; or
(iii)
the variation of the terms of this Agreement or any Credit to give effect to the exercise of the write-down and conversion powers of any EEA Resolution Authority.


37




Very truly yours,
TERP Spanish HoldCo, S.L.
By: /s/ Ricardo Arias Sainz    
Date: 6 – March – 2018    





Acknowledged and agreed:
Natixis, New York Branch

By: /s/ Jonathan J. Kim
 
Name: Jonathan J. Kim
 
Title: Managing Director
 
By: /s/ Guillaume de Parscau
 
Name: Guillaume de Parscau
 
Title: Managing Director
 






EXHIBIT I


Form of L/C Application







                       New York Branch
1251 Avenue of the Americas, 5th Floor, New York, NY 10020
APPLICATION FOR STANDBY LETTER OF CREDIT
 
(Place)
(Date)

 
q    SWIFT (Full details)
 
We request you to establish by
q    Telex (Full details)
An irrevocable Documentary Standby Letter of Credit on the following terms and conditions:
q    Telex (Prime details only)
 
q    Airmail
 

In Favor of
 
 
(Name and Address)
For Account of
 
 
(Name and Address)
Amount
 
Available by drafts at Sight on NATIXIS, New York Branch

Accompanied by the following documents marked X:

q    DOCUMENT REQUIRED: SIGNED STATEMENT BY INDIVIDUAL(S) PURPORTING TO BE AUTHORIZED OFFICER(S) OF THE BENEFICIARY AS FOLLOWS: (PLEASE SUPPLY THE
exact wording of the statement)
 
 
 
 
 
q    OTHER DOCUMENT(S):
 
 
 
 
Partial Drawings
q    PERMITTED
q    NOT PERMITTED
Expiry Date:
 
Special Instructions:
 
 
 
 
 
 
 
the opening of this credit is subject to the terms and conditions as set forth in the standby letter of credit agreement appearing on the reverse hereof to which we agree, and/or, if our continuing agreement is lodged with you, subject to the terms and provisions set forth therein.





 
 
 
(Name of Applicant)
 
By:
 
 
 
 
 
(Name/Title of Signatory/-ies)


standby letter of credit agreement

TO: NATIXIS

In consideration of your opening at our request a standby letter of credit, the terms of which appear on the reverse hereof, we hereby agree with you as follows:

1.
We will pay you on or before the applicable Reimbursement Due Date in lawful money of the United States of America all monies paid by you under or pursuant to said letter of credit, together with interest, commission and all customary charges; we also authorize you to charge any of our accounts with you for all monies so paid or for which you become liable under said letter of credit and we agree, at least forty-five (45) days after the same is due, to provide you with funds to meet all disbursements or payments of any kind or character, together with commission, interest and charges which you have paid or to which you are entitled under or pursuant to said letter of credit.
2.
Neither you nor your correspondents shall be in any way responsible for performance by any beneficiary of its obligations to us, nor for the form, sufficiency, correctness, genuineness, authority of person signing, falsification or legal effect of any documents called for under said letter of credit if such documents on their face appear to be in order.
3.
Subject to the law and customs and practices existing in the area where the beneficiary is located, said letter of credit shall be subject to, and performance by you, your correspondent and the beneficiary thereunder shall be governed by the International Standby Practices, International Chamber of Commerce Publication No. 590 (“ISP98”) or Uniform Customs and Practice for Documentary Credits, 2007 Revision, International Chamber of Commerce Publication No. 600 (The “UCP”).
4.
It is agreed that all directions and correspondence relating to the said letter of credit are to be sent at our risk and that you do not assume any responsibility for any inaccuracy, interruption, error or delay in transmission or delivery by post, telex or other electronic medium, or for any inaccuracy of translation.
5.
The undersigned agree that at all times now and hereafter they will indemnify and save you harmless from and against all loss or damage to you arising in connection with said letter of credit, unless due to negligence on your part, and all costs, charges and expenses and all actions or suits, whether groundless or otherwise, including reasonable and documented counsel fees, it being the purpose of this agreement to fully protect you in the premises.
6.
The execution, delivery and performance of this agreement, and the appointment of the undersigned to execute this agreement on behalf of the Applicant, are within the Applicant’s (or each Applicant’s) power and have been duly authorized by all necessary action.







EXHIBIT II

Form of Bank Guarantee (Spanish Version)
AVAL
[___] (Entidad Avalista), con domicilio social en [___], entidad debidamente registrada en el Registro de Sociedades de [___], con el número [___], representada por [___], mayor de edad, con [documento nacional de identidad / pasaporte] número [___], y [___], mayor de edad, con [documento nacional de identidad / pasaporte], ambos con facultades suficientes para este acto en virtud de [Se incorporarán los detalles del apoderamiento],
AVALA
ante la COMISIÓN NACIONAL DEL MERCADO DE VALORES y en beneficio de los accionistas de la sociedad SAETA YIELD, S.A. que acudan a la oferta pública de adquisición formulada por TERP Spanish Holdco, S.L., con domicilio social en calle Serrano, 21, Madrid, 28001 e inscrita en el Registro Mercantil de Madrid, al tomo 35.995, folio 9, sección 8, hoja M-646.732, inscripción 1ª (el Oferente), sobre las acciones de SAETA YIELD, S.A. (la Oferta), las obligaciones de pago del precio en efectivo asumidas por el Oferente en la Oferta, cuyos términos y condiciones se describen en el folleto explicativo presentado para su registro en la COMISIÓN NACIONAL DEL MERCADO DE VALORES, en cumplimiento de lo dispuesto en el Real Decreto 1066/2007, de 27 de julio, sobre el régimen de las ofertas públicas de adquisición de valores.
La cantidad máxima avalada por la Entidad Avalista es de [___] euros ([___]€).
El presente aval se otorga con carácter incondicional, irrevocable y solidario con respecto a las obligaciones de pago del Oferente derivadas de la Oferta y con renuncia expresa a los beneficios de excusión, orden y división.
El pago de las responsabilidades dimanantes de este aval se llevará a efecto en Madrid, a primer requerimiento de SOCIEDAD DE GESTIÓN DE LOS SISTEMAS DE REGISTRO, COMPENSACIÓN Y LIQUIDACIÓN DE VALORES, S.A. UNIPERSONAL (IBERCLEAR) o de la COMISIÓN NACIONAL DEL MERCADO DE VALORES, mediante requerimiento escrito dirigido a la Entidad Avalista en el siguiente domicilio [___]. Recibido el requerimiento de pago correspondiente, la Entidad Avalista procederá a efectuar el pago del importe correspondiente en la cuenta que el requirente haya designado, en el día hábil siguiente al de la recepción de dicho requerimiento. El presente aval permanecerá en vigor hasta el completo cumplimiento de las obligaciones de pago del Oferente derivadas de la Oferta o, en su caso, hasta la fecha en que la Oferta sea retirada, anulada o declarada sin efecto.
Este aval se rige por la ley española. La Entidad Avalista, con renuncia a cualquier otro fuero que pudiera corresponderle, se somete a los tribunales de la ciudad de Madrid para dirimir cualquier disputa o controversia que pudiese surgir en relación con la interpretación, alcance, cumplimiento, efectos y ejecución del presente aval.
El presente Aval ha sido inscrito en el Registro Especial de Avales con el número [___].
En [Lugar], a [día] de [mes] de [año].
[Denominación social de la Entidad Avalista]
P.p.                                     P.p.

___________________                        __________________
[Name]                                [Name]
[Position]                                [Position]



Form of Bank Guarantee (English translation)
GUARANTEE
[___] (the Guarantor Entity), with registered office at [___], duly registered with the Companies Registry of [___], with number [___], represented by [___], of legal age, with [national identity card number / passport number] [___], and [___] of legal age, with [national identity number / passport number], both with sufficient powers pursuant to [Insert details of relevant powers of attorney].
GUARANTEES
before the COMISIÓN NACIONAL DEL MERCADO DE VALORES and for the benefit of the shareholders of SAETA YIELD, S.A. who accept the takeover offer launched by TERP Spanish Holdco S.L., with registered office at 21 calle Serrano, Madrid, 28001 and duly registered with the Companies Registry of Madrid, at book 35,995, volume 9, section 8, sheet M-646,732, entry 1 (the Bidder), over the shares in SAETA YIELD, S.A. (the Offer), the obligations assumed by the Bidder regarding the payment in cash of the consideration of the Offer, which terms and conditions are described in the Offer prospectus which has been filed for registration with the COMISIÓN NACIONAL DEL MERCADO DE VALORES, in accordance with the provisions of Royal Decree 1066/2007, of July 27, on public takeover bids for securities.
The maximum amount guaranteed by the Guarantor Entity is Euro [___] (€[___]).
This guarantee unconditionally, irrevocably and jointly and severally guarantees the payment obligations of the Bidder arising under the Offer, with express waiver of the benefits of ranking, priority and separation (excusión, orden y división).
Payment of the amounts payable under this guarantee will be made in Madrid on first demand for payment made by SOCIEDAD DE GESTIÓN DE LOS SISTEMAS DE REGISTRO, COMPENSACIÓN Y LIQUIDACIÓN DE VALORES, S.A. UNIPERSONAL (IBERCLEAR) or by the COMISIÓN NACIONAL DEL MERCADO DE VALORES, made in writing and addressed to the Guarantor Entity at the following address: [___]. Once the demand for payment is received, the Guarantor Entity will make the corresponding payment to the account indicated on the demand on the Business Day following receipt of the relevant payment demand.
This guarantee will remain in full force and effect until the payment obligations of the Bidder arising under the Offer have been discharged in full or, if applicable, until the date the Offer is withdrawn, annulled or declared as without effect.
This guarantee is governed by Spanish law. The Guarantor Entity, waiving the right to any other jurisdiction which it may be entitled to, submits to the jurisdiction of the courts of the city of Madrid to resolve any dispute or disagreement that could arise in relation to the interpretation, scope, performance, effect and enforcement of this guarantee.
This guarantee has been registered on the Special Registry of Guarantees with number [___].
In [Place], on [day] [Month] [year].
[Registered name of the Guarantor Entity]
By                                     By
___________________                        __________________
[Name]                                [Name]
[Position]                                [Position]



Exhibit


EXECUTION VERSION


Exhibit 10.20
March 6, 2018
TerraForm Power, Inc.
7550 Wisconsin Ave.
Bethesda, MD 20814
Ladies and Gentlemen:
Reference is made to that certain Continuing Agreement for Letters of Credit, dated as of March 6, 2018 (as amended, modified, supplemented and in effect from time to time, the “LC Agreement”), entered into concurrently with the execution and delivery of this letter agreement (this “Agreement”), by TERP Spanish HoldCo, S.L. (the “Applicant”) and Natixis, New York Branch (the “Issuing Bank”), pursuant to which the Issuing Bank has agreed to provide Credits to be used by Applicant to secure the Applicant’s obligation of full payment of the cash consideration under the Applicant’s takeover bid (the “Offer”) which has been launched for all of the outstanding shares of Saeta Yield, S.A. (“SAY”) vis-à-vis the Comisión Nacional del Mercado de Valores or the “Sociedad de Gestión de los Sistemas de Registro, Compensación y Liquidación de Valores, S.A. Unipersonal”, as the entity responsible for the Spanish clearing and settlement system, and for the benefit of the SAY shareholders accepting the Offer, all in accordance with Royal Decree 1066/2007, of 27 July, on the rules applicable to public takeover bids for securities (Real Decreto 1066/2007, de 27 de julio, sobre el régimen de las ofertas públicas de adquisición de valores –“RD 1066/2007”). Unless otherwise specified herein, all capitalized terms used and not otherwise defined herein will have the meanings ascribed to them in the LC Agreement.
By its signature below, Terraform Power, Inc. (the “Parent”) hereby: (i) acknowledges and confirms that (a) it is a condition precedent to the effectiveness of the LC Agreement and issuance of Credits thereunder that the Parent shall have executed and delivered this Agreement, (b) Parent has agreed to take (and/or cause TPO to take) any actions necessary to cause or permit the Applicant to comply with its obligations under the last paragraph of Section 8 (Default) and clauses (i) and (k) of Section 16(iii) of the LC Agreement in order to finance the funding of any cash collateral account pursuant to the last paragraph of Section 8 (Default) of the LC Agreement (“Cash Collateral Deposit”) and the repayment of any outstanding Draft and (c) each of the Credit Parties



will derive economic benefit from the Credits; and (ii) hereby agrees with the Issuing Bank as follows:
1.Parent hereby represents and warrants to and in favor of Issuing Bank and the Aval Provider, as of the date hereof and of the issuance or amendment of any Credit, as follows (which representations and warranties shall survive the execution and delivery of this Agreement):
(a)    Parent (i) is familiar with, and has independently reviewed, books and records regarding the financial condition of other Credit Parties and (ii) has reviewed and is familiar with the Facility Documents and other documents relating thereto that are material to its obligations hereunder;
(b)    Parent directly or indirectly owns one hundred percent (100%) of the equity interests in each of TPO, NSF and the Applicant, excluding any incentive distribution rights in TPO (as in effect on the date hereof);
(c)    Parent is not executing this Agreement with any intention to hinder, delay or defraud any of its or the other Credit Parties creditors;
(d)    Parent (i) is duly incorporated, validly existing and in good standing under the laws of the State of Delaware and (ii) is duly qualified to do business and in good standing in each jurisdiction in which such qualification is necessary to execute, deliver and perform this Agreement;
(e)    Parent has the corporate power and authority to execute, deliver and perform this Agreement and to take all corporate action as may be necessary to complete the transactions contemplated hereunder. The Parent has taken all necessary action to authorize the execution, delivery and performance of this Agreement and to complete the transactions contemplated hereby. No consent or authorization of, filing with, or other act by or in respect of any other Person or Governmental Authority is required in connection with the execution, delivery or performance by the Parent, or the validity or enforceability as to the Parent, of this Agreement, except such consents, authorizations, filings or other acts as have already been obtained or made. This Agreement has been duly executed and delivered by the Parent and constitutes a legal, valid and binding obligation of the Parent enforceable against it in accordance with its terms, except as enforceability may be limited by applicable bankruptcy, insolvency, reorganization, moratorium or similar laws affecting the right of creditors generally and by general principles of equity;
(f)    The execution, delivery and performance by the Parent of this Agreement, and the consummation of the transactions contemplated hereby (including the performance by the Parent of any of its obligations hereunder),

2



does not violate any law, any provision of the certificate of formation, operating agreement or other organizational documents of any Credit Party or violate any contractual obligation of any Credit Party, and will not result in, or require, the creation or imposition of any lien on any of their respective properties or revenues pursuant to any such requirement of law or any such contractual obligation, except, in each case (other than the Backstop Agreements and Cobra Irrevocable Agreement) where such violations could not (individually or in the aggregate) reasonably be expected to have a Material Adverse Effect;
(g)    Parent is in compliance with all requirements of applicable law, except to the extent any non-compliance could not reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder;
(h)    No litigation or proceeding of or before any arbitrator or Governmental Authority is pending or, to the Parent’s knowledge, threatened against or affecting the Parent or any of its properties or assets or the transactions contemplated by this Agreement and the other Facility Documents in each case which, if adversely determined, would reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder;
(i)    Each financial statement and financial report of Parent heretofore delivered to Issuing Bank pursuant to the Facility Documents fairly represents, in all material respects, the financial position of Parent and its consolidated subsidiaries as at the respective dates thereof and the results of operations and the changes in cash flows of Parent and its consolidated subsidiaries for each of the periods then ended, except as otherwise noted therein and subject, in the case of any such unaudited financial statements, to changes resulting from audit and normal year-end adjustments;
(j)    Neither Parent nor any of its subsidiaries is (i) subject to regulation under the Investment Company Act of 1940 (as amended) or (ii) a “registered investment company” or a company “controlled” by a “registered investment company” or a “principal underwriter” of a “registered investment company” as such terms are defined in the Investment Company Act of 1940 (as amended);
(k)    None of Parent and its subsidiaries (the “Parent Group”), nor any of Parent’s or their respective joint ventures, directors, officers or employees nor, to Parent’s knowledge, any Persons acting on any of their behalf (a) is a Restricted Party; or (b) has received notice of or is aware of any claim, action, suit, proceeding or investigation against it with respect to Sanctions by any Sanctions Authority; and

3



(l)    The operations of each member of the Parent Group are and have been conducted at all times in compliance with all applicable Anti-Money Laundering Laws, Anti-Terrorism Laws and Anti-Corruption Laws and no action, suit or proceeding by or before any Governmental Authority or any arbitrator involving a member of the Group with respect to Anti-Money Laundering Laws, Anti-Terrorism Laws and/or Anti-Corruption Laws is pending and no such actions, suits or proceedings are threatened or contemplated.
2.    The Parent hereby covenants and agrees for the benefit of the Issuing Bank and the Aval Provider that:
(a)    Parent shall maintain and preserve (i) its existence as a corporation in good standing in the state of its formation and its qualification to do business in each other jurisdiction where such qualification is necessary to perform its obligations hereunder and (ii) all material rights, privileges and franchises necessary in the normal course of conduct of its business, except any such rights, qualifications, privileges and franchises the failure to maintain would not reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder or thereunder;
(b)    Parent shall comply with all requirements of applicable law, except where such non-compliance would not reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder;
(c)    Parent shall not, and will not permit or authorize any other Person to, directly or indirectly, use, lend, make payments of, contribute or otherwise make available, all or any part of the proceeds of any Credit or other transaction(s) contemplated by the Facility Documents to fund any trade, business or other activities: (i) involving or for the benefit of any Restricted Party, or (ii) in any other manner that would reasonably be expected to result in any member of the Parent Group or Issuing Bank or Aval Provider being in breach of Sanctions, Anti-Money Laundering Laws, Anti-Terrorism Laws and/or Anti-Corruption Laws (if and to the extent applicable to them) or becoming a Restricted Party;
(d)    Parent shall not at any time cease to own and control, (A) directly or indirectly, 100% of the securities having ordinary voting power for the election of directors (or persons performing similar functions) of TPO and NSF, excluding any incentive distribution rights in TPO (as in effect on the date hereof), and (B) directly, or indirectly through TPO and NSF, 100% of the voting power of the membership interests and economic interests of the Applicant, excluding any incentive distribution rights in TPO (as in effect on the date hereof);
(e)    Parent shall cause to be maintained minimum amounts available to be drawn at all times under the Backstop Agreements as follows: (1) no less than

4



US$400,000,000 under the Revolver and (2) no less than US$500,000,000 under the Sponsor Line. Parent shall provide evidence reasonably acceptable to Issuing Bank promptly upon written request that, that such minimum availability exists under the Backstop Agreements;
(f)    Parent shall not cause or permit the creation of, nor assume or suffer to exist, any lien on equity capital of NSF or the Applicant which secures a charge or obligation on any of such equity capital, real or personal, whether now owned or hereafter acquired, except as otherwise permitted pursuant to the Facility Documents;
(g)    Parent shall not cause, make, suffer, permit or consent to any creation, sale, assignment or transfer of any ownership interest or other interest in NSF, TPO or the Applicant, except as expressly contemplated by the Facility Documents or otherwise permitted by the Issuing Bank;
(h)    Parent shall not cause, make, suffer, permit or consent to any modification of, or amendment, waiver or termination of, any of the Backstop Agreements or Irrevocable Agreements or any of the agreements or documents relating to the Santander Facility that is in any manner adverse to the Issuing Bank; and
(i)    In the event that either (1) Issuer shall demand that Applicant fund any Cash Collateral Deposit pursuant to the last paragraph of Section 8 (Default) of the LC Agreement or (2) any Draft is made on a Credit, Parent shall:
(i)    promptly (and in any event not more than (x) three (3) Business Days following such demand or Draft with respect to any drawing described in sub-clause (a) immediately below or (y) forty-five (45) days following such demand or Draft with respect to any issuance described sub-clause (b) immediately below), take (and/or cause its applicable subsidiaries, including TPO, to take) the following actions to the extent required to ensure that the Applicant has immediately available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding Draft (together with any other Obligations then payable) and any corresponding collateralization, reimbursement or other obligations due under the Santander Facility:
(a)    first, cause TPO to submit a request for and draw the maximum amount available to be drawn under the Revolver and/or submit a request for and draw the maximum amount available to be drawn under the Sponsor Line; and

5



(b)    second, issue and sell new shares of Class A common stock in Parent for net proceeds in an amount not to exceed US$400 million; and
(ii)    promptly (and in any event not more than forty-five (45) days following the applicable demand or Draft), make (and/or cause its applicable subsidiaries, including TPO, to make) equity contributions to Applicant (utilizing in whole or in part, in its sole discretion, an amount up to the net proceeds resulting from such drawings and/or issuance) to the extent required to ensure that the Applicant has immediately available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding Draft (together with any other Obligations then payable) and any corresponding collateralization, reimbursement or other obligations due under the Santander Facility; provided that, notwithstanding the foregoing, in any event Parent shall contribute or cause to be contributed (and/or cause its applicable subsidiaries (including TPO) to contribute) the amounts required to be requested pursuant to Section 2(i)(i)(A) in an amount equal to the lesser of (x) US$900,000,000 and (y) the amount of any demanded cash collateral and (without duplication) outstanding Draft (together with any other Obligations then payable) to Applicant not more than eight (8) Business Days following the applicable demand or Draft.
3.    All rights of the Issuing Bank and all obligations of the Parent hereunder shall be absolute and unconditional irrespective of: (i) any lack of validity, legality or enforceability of this Agreement, the other Facility Documents or the Backstop Agreements; (ii) the failure of Issuing Bank (A) to assert any claim or demand or to enforce any right or remedy against the Applicant, the Parent or any other Person (including any guarantor) under the provisions of the Facility Documents, the Backstop Agreements or otherwise, or (B) to exercise any right or remedy against any other Credit Party; (iii) any change in the time, manner or place of payment of, or in any other term of, all or any portion of the obligations of, or any other extension or renewal of any obligation of the Applicant, Parent, the other Credit Parties; (iv) any reduction, limitation, impairment or termination of any of the obligations of the Applicant, Parent, the other Credit Parties for any reason other than the written agreement of the Issuing Bank, and shall not be subject to, and the Parent hereby waives any right to or claim of, any defense or setoff, counterclaim, recoupment or termination whatsoever by reason of the invalidity, illegality, non-genuineness, irregularity, compromise or unenforceability of, or any other event or occurrence affecting, any obligation of the Applicant, the Parent, the other Credit Parties or otherwise; (v) any amendment to, waiver or other modification of, or any consent to departure from, any of the terms of this Agreement or the other Facility Documents; or (vi) any other circumstance which might otherwise constitute a defense

6



available to, or a legal or equitable discharge of, Applicant, the Parent, the other Credit Parties (other than the defense of payment of the applicable amounts).
4.    The Issuing Bank acknowledges and agrees that Parent’s obligations under this Agreement are as expressly set forth herein and that such obligations are not intended to, and do not, constitute a guarantee by Parent of Applicant’s Obligations under the LC Agreement.
5.    The Issuing Bank and Aval Provider may demand specific performance of this Agreement. The Parent hereby irrevocably waives, to the extent it may do so under applicable law, any defense based on the adequacy of a remedy at law that may be asserted as a bar to the remedy of specific performance in any action brought against the Parent for specific performance of this Agreement by the Issuing Bank, the Aval Provider or any successor or assign thereof.
6.    This Agreement shall be governed and construed in accordance with the laws of the State of New York. For the purposes of any proceeding, action or suit involving this Agreement, each party hereto hereby expressly submits to the jurisdiction of any court of record of New York State or the United States located in the City of New York, Borough of Manhattan, and agrees that any order, process or other paper may be served upon either party within or without such court’s jurisdiction by mailing a copy thereof to the affected party at its address (that with respect to Issuing Bank, shall be Issuing Bank’s address shown on the first page of the LC Agreement, and with respect to Parent, shall be Parent’s address shown on the first page of this Agreement). Parent agrees that service of all process in any such proceeding in any such court may be made by registered or certified mail, return receipt requested, to such address and agrees that service as provided above is sufficient to confer personal jurisdiction over Parent in any such proceeding in any such court, and otherwise constitutes effective and binding service in every respect. Each party waives any claim that such proceeding, action or suit has been brought in an inconvenient forum. EACH PARTY WAIVES TRIAL BY JURY.
7.    Neither this Agreement nor any provision hereunder may be amended, modified, supplemented or waived except in a writing signed by the Parent and the Issuing Bank.
8.    This Agreement may be executed in two or more counterparts, each of which shall be deemed to be an original, but all of which together shall constitute one and the same instrument, and shall become effective when one or more counterparts have been signed by each of the parties and delivered to the other parties.
[The next page is the signature page]


7




IN WITNESS WHEREOF, the parties hereto have executed this Agreement as of the date above first written.
Very truly yours,
 
NATIXIS, NEW YORK BRANCH

 
By
/s/ Jonathan J. Kim
 
Name:
Jonathan J. Kim
 
Title:
Managing Director

By
/s/ Guillaume de Parscau
 
Name:
Guillaume de Parscau
 
Title:
Managing Director


CONFIRMED AND AGREED TO:

TERRAFORM POWER, INC.
 
By
/s/ Andrea Rocheleau
 
Name:
Andrea Rocheleau
 
Title:
General Counsel and Secretary



 
Exhibit
EXECUTION


Exhibit 10.21




March 6, 2018
BANCO SANTANDER, S.A.
Avenida Gran Vía de Hortaleza, 3
Edificio Pedreña
28033 Madrid
España
Re: Agreement for Bank Guarantee (theAgreement)
Ladies and Gentlemen,
In consideration of TERP Spanish HoldCo, S.L.’s (the “Applicant”) request that Banco Santander, S.A. (the “Aval Provider”) issue a bank guarantee, in the form attached hereto as Exhibit I (the “Bank Guarantee”), in accordance with the terms hereof, the parties hereto hereby undertake as follows:
1.
Object. Certain Definitions
1.1
Upon satisfaction of all conditions set forth in Section 7 (Conditions Precedent) below and: (i) the Stated Amount (as defined below) of the Bank Guarantee issued under this Agreement not exceeding the amount of €497,619,261 (the “Facility Amount”) and; (ii) no Default (as defined below) or Event of Default (as defined below) shall have occurred and be continuing, the Aval Provider will issue the Bank Guarantee pursuant to its commitment under this Agreement to guarantee the obligations of the Applicant in respect of the full payment of the cash consideration under the takeover bid announced by the Applicant for all of the outstanding shares of Saeta Yield, S.A. (“SAY” and the “Offer”) vis-à-vis the Comisión Nacional del Mercado de Valores (the “CNMV”) or the “Sociedad de Gestión de los Sistemas de Registro, Compensación y Liquidación de Valores, S.A. Unipersonal” (“Iberclear”), as the entity responsible for the Spanish clearing and settlement system, and for the benefit of the SAY shareholders accepting the Offer, all in accordance with Royal Decree 1066/2007,





of 27 July, on the rules applicable to public takeover bids for securities (Real Decreto 1066/2007, de 27 de julio, sobre el régimen de las ofertas públicas de adquisición de valores –“RD 1066/2007”). The Applicant will need to provide the CNMV with evidence of the existence of the Bank Guarantee when filing the request for authorization of the Offer or within not more than seven business days of such date.
1.2
As used herein, the following terms shall have the following meanings:
Agreement” has the meaning assigned to it in the reference paragraph of this letter.
Anti-Corruption Laws” means the United States Foreign Corrupt Practices Act of 1977, the UK Bribery Act of 2010 and any related or similar laws, rules, regulations or guidelines, which in each case are issued, administered or enforced by the United States of America, the European Union and any of its member states or any Governmental Authority having jurisdiction over any member of the Group, or to which any member of the Group is subject.
Anti-Money Laundering Laws” means all applicable financial recordkeeping and reporting requirements and the money laundering statutes and the rules and regulations thereunder and any related or similar rules, regulations or guidelines, which in each case are issued, administered or enforced by any Governmental Authority having jurisdiction over any member of the Group, or to which any member of the Group is subject.
Applicable Rate” means the applicable rate per annum set forth below:
Period
Applicable Rate
For any quarterly period ending on or before August 31, 2018
0.60%
For any quarterly period ending after August 31, 2018 and on or before March 7, 2019
0.85%
For any quarterly period ending after March 7, 2019 and on or before March 7, 2020
1.35%
For any quarterly period ending after March 7, 2020
1.80%
Applicant” has the meaning assigned to it in the introductory paragraph.
Articles of Association” means the charter documents, articles of association, operating agreements and other organizational documents of any Person.
Aval Provider” has the meaning assigned to it in the introductory paragraph.

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Backstop Agreements” means, collectively:
(a)
the Credit and Guaranty Agreement, dated as of October 17, 2017, among TPO, as borrower, TerraForm Power, LLC, as a guarantor, certain subsidiaries of TPO, as guarantors, the lenders party thereto from time to time, and HSBC Bank USA, National Association, as administrative agent and collateral agent (the “Revolver”);
(b)
the Credit Agreement, dated as of October 16, 2017, by and among Parent, as borrower, and Brookfield Asset Management Inc., a corporation existing under the laws of the Province of Ontario, and Brookfield Finance Luxembourg S.à r.l., a société à responsabilité limitée organized under the laws of the Grand Duchy of Luxembourg, as Lenders (the “Sponsor Line”); and
(c)
the Support Agreement dated as of February 6, 2018 by and among Parent and Brookfield Asset Management Inc. (the “Support Agreement”).
Bank Guarantee” has the meaning assigned to it in the introductory paragraph above.
Bank Recovery and Resolution Directive” means Directive 2014/59/EU of the European Parliament and of the Council of the European Union.
Base Rate” means the prime commercial lending rate (which is not necessarily the lowest rate charged by the Aval Provider on loans or other extensions of credit) published by the Aval Provider from time to time, changing as and when said prime rate shall change. Any change in the rate of interest provided for herein based on a change in the Aval Provider’s prime rate shall take effect on the date of the change in the Aval Provider’s prime rate.
Business Day” means a day on which banks are open for business in New York and Madrid, Spain.
Capital Lease Obligations” means with respect to any Person means the obligations of such Person to pay rent or other amounts under any lease of (or other arrangement conveying the right to use) real or personal property, or a combination thereof, which obligations are required to be classified and accounted for as capital leases on a balance sheet of such Person under IFRS, and the amount of such obligations shall be the capitalized amount thereof determined in accordance with IFRS.

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Change of Control” means the consummation of any transaction or series of transactions as a result of which Parent shall cease to own and control:
(a)
directly or indirectly, 100% of the securities having ordinary voting power for the election of directors (or persons performing similar functions) of TPO and NSF, excluding any incentive distribution rights in TPO (as in effect on the date hereof);
(b)
directly, or indirectly through TPO and NSF, 100% of the voting power of the membership interests and economic interests of the Applicant, excluding any incentive distribution rights in TPO (as in effect on the date hereof).
CNMV” means the Comisión Nacional del Mercado de Valores.
Credit Parties” means, collectively, Parent, TPO, NSF and Applicant.
Default” means any of the events specified in Section 8 (Default), whether or not any requirement for the giving of notice, the lapse of time, or both, has been satisfied.
Dollars”, “U.S. Dollars”, “USD$” and the sign “$” mean the lawful money of the United States of America.
Effective Date” has the meaning assigned to it in Section 7.1 (Conditions Precedent).
Euros” and the sign “” mean the single currency of the Participating Member States.
Event of Default” means any of the events specified in Section 8 (Default), provided that any requirement for the giving of notice, the lapse of time, or both, has been satisfied
Excluded Taxes” has the meaning assigned to it in Section 4 (Increased Costs and Taxes).
Facility Amount” has the meaning assigned to it in this Section 1 (Object. Certain Definitions) above.
Facility Documents” means each of the following, in full force and effect and satisfactory to the the Aval Provider:
(a)
this Agreement;
(b)
an intercreditor agreement with Natixis, New York Branch (the “Intercreditor Agreement”), as issuer under the Applicant’s other bank guarantee, dated as of the date hereof, relating to the Offer and formalized through a continuing agreement for letters of credit (the “Natixis Facility”);

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(c)
those two certain comfort letter agreements, dated as of the date of this Agreement, issued by Brookfield Asset Management Inc. and Parent (respectively) in favor of the Aval Provider; and
(d)
other documents designated by the Aval Provider acting reasonably.
Governmental Authority” means any nation or government, any state, provincial or other political subdivision thereof, and any agency, authority, instrumentality, regulatory body, court, central bank or other entity exercising executive, legislative, judicial, taxing, regulatory or administrative functions of or pertaining to government.
Group” means Applicant and its subsidiaries.
Hedging Obligations” means with respect to any specified Person, the obligations of such Person under:
(a)
interest rate swap agreements (whether from fixed to floating or from floating to fixed), interest rate cap agreements and interest rate collar agreements;
(b)
other agreements or arrangements designed to manage interest rates or interest rate risk; and
(c)
other agreements or arrangements designed to protect such Person against fluctuations in currency exchange rates or commodity prices.
Iberclear” means “Sociedad de Gestión de los Sistemas de Registro, Compensación y Liquidación de Valores, S.A. Unipersonal”, the entity responsible for the Spanish clearing and settlement system.
IFRS” means international accounting standards within the meaning of IAS Regulation 1606/2002 to the extent applicable to the relevant financial statements in effect as of the date of determination thereof.
Indebtedness” means with respect to any specified Person, any debt of such Person (excluding accrued expenses and trade payables), whether or not contingent:
(a)
in respect of borrowed money;
(b)
evidenced by bonds, notes, debentures or similar instruments;
(c)
in respect of letters of credit, banker’s acceptances or other similar instruments (or reimbursement agreements in respect thereof);

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(d)
representing Capital Lease Obligations;
(e)
representing the balance deferred and unpaid of the purchase price of any property or services due more than sixty (60) days after such property is acquired or such services are completed; or
(f)
representing any Hedging Obligations,
if and to the extent any of the preceding items (other than letters of credit and Hedging Obligations) would appear as a liability upon a balance sheet of the specified Person prepared in accordance with IFRS.
Indemnified Person” has the meaning assigned to it in Section 5 (Indemnification).
Indemnified Taxes” means taxes other than Excluded Taxes (defined above), including but not limited to, any and all current or future recording, stamp, documentary, excise, transfer, sales or similar taxes, charges or levies arising from any payment made under any guarantee or from the execution, delivery or enforcement of, or otherwise with respect to, any Bank Guarantee.
Irrevocable Agreements means, collectively:
(a)
the Irrevocable Undertaking Agreement entered into in relation to the Offer dated as of February 6, 2018 between Applicant, Cobra Concesiones, S.L. and GIP II Helios, S.à r.l. (the “Cobra Irrevocable Agreement”);
(b)
the Irrevocable Undertaking Agreement entered into in relation to the Offer, dated as of February 6, 2018 between Applicant and Mutuactivos, S.A.U., S.G.I.I.C. (the “Mutuactivos Irrevocable Agreement”); and
(c)
that certain Irrevocable Undertaking Agreement entered into in relation to the Offer, dated as of February 6, 2018 between Applicant and Sinergia Advisors 2006, A.V., S.A. (the “Sinergia Irrevocable Agreement”).
Material Adverse Effect” means a material adverse change in or a material adverse effect on:
(a)
the business, operations, properties, assets or condition (financial or otherwise) of the Applicant and the Credit Parties, taken as a whole;
(b)
the ability of Applicant to fully and timely perform its obligations under this Agreement;

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(c)
the legality, validity, binding effect or enforceability against any Applicant of this Agreement; or
(d)
the rights and remedies available to, or conferred upon, the Aval Provider under this Agreement.
Natixis Facility” has the meaning assigned to it under the definition of “Facility Documents” above.
NSF” means Norrington Solar Farm Limited.
Obligations has the meaning assigned to it in Section 4 (Increased Costs and Taxes).
Offer” means Applicant’s takeover bid which has been announced for all of the outstanding shares of Saeta Yield, S.A. (“SAY”), and the SAY shareholders potentially accepting the Offer, all in accordance with Royal Decree 1066/2007, of 27 July, on the rules applicable to public takeover bids for securities (Real Decreto 1066/2007, de 27 de julio, sobre el régimen de las ofertas públicas de adquisición de valores –RD 1066/2007”).
Offer Documents” means the final documentation for the Offer, including the authorization request to launch the Offer submitted to CNMV, the announcement of the Offer and the Offer document (folleto informativo) in the form approved by the CNMV.
Parent” means TerraForm Power, Inc.
Participating Member State” means any member state of the European Union that has the Euro as its lawful currency in accordance with legislation of the European Union relating to Economic and Monetary Union.
Person” means an individual, partnership, corporation, limited liability company, business trust, joint stock company, trust, unincorporated association, joint venture, Governmental Authority or other entity of whatever nature.
Responsible Officer” has the meaning assigned to it in Section 15.2.1.
Spanish GAAP” means the requirements applicable to the financial statements and accounts set forth in the Spanish Stock Corporations Act (Ley de Sociedades de Capital), the General Accounting Plan in force in Spain and all resolutions issued by the ICAC (Instituto de Contabilidad y Auditoría de Cuentas), together with accounting principles, standards and practices which are generally accepted in Spain as at the date of the relevant financial statements or accounts.

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Spot Rate” means the rate determined by the Aval Provider as:
(a)
the exchange rate reported by Bloomberg as of the end of the second TARGET2 Day preceding the date of payment or other determination, or
(b)
if such report is unavailable for any reason, the spot rate for the purchase of Euros with U.S. Dollars as in effect during the second Business Day preceding the date of payment or other determination in the Aval Provider’s principal foreign exchange trading office for Euros; provided that the Aval Provider may obtain such spot rate from another nationally recognized financial institution designated by the Aval Provider if it does not have as of the applicable date of payment or other determination a spot buying rate for the purchase of Euros with U.S. Dollars.
Stated Amount” means the amount secured under the Bank Guarantee issued under this Agreement, which will not exceed the Facility Amount (as defined in Section 1Object. Certain Definitions– above).
TARGET2 Day” means any day on which TARGET2 (or, if such payment system ceases to be operative, such other payment system, if any, determined by the Aval Provider to be a suitable replacement therefor) is open for the settlement of payments in Euros.
TARGET2” means the Trans-European Automated Real-time Gross settlement Express Transfer payment system which utilizes a single shared platform and which was launched on November 19, 2007.
TPO” means TerraForm Power Operating, LLC.
2.
Payment for and execution of the Bank Guarantee
2.1
Applicant agrees to reimburse the Aval Provider in Euros, the amount of any payment or disbursement under the Bank Guarantee.
2.2
Applicant’s obligation to make payments in Euros hereunder shall not be satisfied by any tender, or any recovery by the Aval Provider pursuant to the Intercreditor Agreement or any judgment, which is expressed in or converted into any currency other than Euros, except to the extent that such tender or recovery results in the actual receipt by the Aval Provider in Spain of the full amount of Euros payable under this Agreement.
3.    Payment for Services Rendered
3.1
The Applicant agrees to pay the Aval Provider’s usual and customary charges for the issuance of any Bank Guarantee and for any wire transfers.

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3.2
In addition, Applicant shall pay the Aval Provider in Euros:
3.2.1
a one-time upfront fee on the third (3rd) Business Day following the Effective Date in an amount equal to 0.20% of the Facility Amount, earned and due and payable in Euros upon the issuance of a Bank Guarantee pursuant to this Agreement;
3.2.2
a fee payable in Euros in arrears of every quarterly period (or the portion thereof) to take place during the term of this Agreement (the first quarterly period commencing on March 7, 2018), on the last Business Day of every quarterly period and on the last Business Day of the term of this Agreement, equal to the product of: (1) (x) the daily average Stated Amount outstanding for the relevant quarterly period (or portion thereof) multiplied by (y) a fraction, the numerator of which is the number of days in such quarterly period (or portion thereof) and the denominator of which is 360, multiplied by (2) the corresponding Applicable Rate;
3.2.3
upon the Aval Provider’s written demand, from and after the occurrence of an Event of Default or any event of default under any other direct agreements between the Aval Provider and any of its affiliates (on the one hand) and a Credit Party (on the other hand) interest on any amounts payable hereunder (including any fees and any required reimbursement), at the then-prevailing interest rate hereunder (including the Applicable Rate) plus 2.00% to the date of payment by Applicant (said interest to be calculated on the basis of the actual number of days elapsed in a 360-day year); and
3.2.4
promptly upon the Aval Provider’s written demand, all liabilities, charges and reasonable expenses (including reasonable and properly documented out-of-pocket attorneys’ fees and expenses) paid by or incurred by the Aval Provider in connection with a Bank Guarantee or this Agreement or the enforcement hereof.
3.3
Subject to the immediately following paragraph and Section 7 (Conditions Precedent) below, interest shall be payable on any outstanding and unreimbursed amounts due to the Aval Provider pursuant to this Agreement from the date on which the relevant amount is payable until the date of repayment in full in Euros and in immediately available funds at a rate equal to the Base Rate plus the Applicable Rate.
4.    Increased Costs and Taxes
4.1
If the Aval Provider determines that the introduction or effectiveness of, or any change in, any law or regulation or compliance with any guideline or request (whether or not having the force of law) from any Governmental Authority which affects or would affect the amount of capital or reserves required or expected to be maintained by the Aval Provider, and the Aval Provider determines that the amount of such capital or reserves is increased by or based

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upon the existence of any Bank Guarantee then the Applicant shall pay to the Aval Provider promptly upon the Aval Provider’s written demand therefor, from time to time, additional amounts in Euros sufficient in the Aval Provider’s judgment to compensate for the increase. For the avoidance of doubt, the Aval Provider’s certificate as to amounts due hereunder shall be conclusive, in the absence of manifest error.
4.2
Any and all payments by or on account of any of Applicant’s obligations hereunder (the “Obligations”) shall be made free and clear of and without reduction or withholding for any Indemnified Taxes imposed by or within the jurisdiction of Applicant’s organization, or the jurisdiction from which payment hereunder is being made, provided that if Applicant shall be required by applicable law to deduct any Indemnified Taxes from such payments, then:
4.2.1
the sum payable shall by increased as necessary so that after making all required deductions (including deductions applicable to additional sums payable under this section), the Aval Provider receives an amount in Euros equal to the sum it would have received had no such deductions been made;
4.2.2
Applicant shall make such deductions; and
4.2.3
Applicant shall pay the full amount deducted to the relevant Governmental Authority in accordance with applicable law.
4.3
In addition, Applicant shall indemnify the Aval Provider for, and hold the Aval Provider harmless against, the full amount of Indemnified Taxes (including any taxes of any kind imposed or asserted by any jurisdiction on amounts payable under this section) imposed on or paid by the Aval Provider or any affiliate of the Aval Provider in respect of any liability (including penalties, interest and expenses) arising therefrom or with respect thereto, whether or not such Indemnified Taxes were correctly or legally asserted. Payment under this indemnity shall be made within thirty (30) days from the date the Aval Provider makes written demand therefor.
4.4
Within thirty (30) days after the date of any payment of Indemnified Taxes, Applicant shall furnish to the Aval Provider at the Aval Provider’s address listed above, the original or a certified copy of a receipt evidencing such payment. In case of any payment hereunder by or on behalf of Applicant, if Applicant determines that no Indemnified Taxes are payable in respect thereof, Applicant shall, at the Aval Provider’s request, furnish, or cause the payor to furnish, to the Aval Provider an opinion of counsel acceptable to the Aval Provider in form and substance acceptable to the Aval Provider stating that such payment is exempt from Indemnified Taxes.

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4.5
Notwithstanding anything to the contrary provided elsewhere in this Agreement and/or the relevant Bank Guarantee, Applicant shall not be liable to make any payment to the Aval Provider pursuant to this Section 4 for, or in relation to the following taxes:
4.5.1
taxes, franchise taxes and similar taxes measured by, or assessed against, the Aval Provider’s net income, profit or capital and imposed by the jurisdiction in which the Aval Provider’s principal office is situated; and
4.5.2
any taxes that would not be imposed but for a connection between the Aval Provider and such taxing jurisdiction, or any political subdivision thereof of taking authority therein, other than as a result of this Agreement or taxes imposed by the Kingdom of Spain (the “Excluded Taxes”).
5.    Indemnification
5.1
Applicant agrees to indemnify and hold the Aval Provider and its correspondents and its officers, directors, affiliates, employees, attorneys, advisors, consultants and agents (each an “Indemnified Person”) harmless against any and all claims, losses, costs, expenses, liabilities or damages, including reasonable and properly documented out-of-pocket attorney fees and other dispute resolution expenses related thereto, howsoever arising from or in connection with:
5.1.1
the issuance of a Bank Guarantee and/or the transactions contemplated hereby;
5.1.2
any payment or action taken or omitted to be taken in connection with a Bank Guarantee (including any action or proceeding seeking:
5.1.2.1
to restrain any drawing under a Bank Guarantee;
5.1.2.2
compel or restrain the payment of any amount or the taking of any other action under any Bank Guarantee;
5.1.2.3
to compel or restrain the taking of any action under this Agreement or any other Facility Document; or
5.1.2.4
to obtain similar relief (including by way of interpleader, declaratory judgment, attachment or otherwise), regardless of who the prevailing party is in any such action or proceeding),
5.1.3
the enforcement of this Agreement or any other Facility Document; or
5.1.4
any act or omission, whether rightful or wrongful, of any present or future de jure or de facto Governmental Authority or any other cause beyond the Aval Provider’s control,

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except in each of 5.1.1 through 5.1.4 above, to the extent that such claim, loss, cost, expense, liability or damage is found by a court of competent jurisdiction (in a final and non-appealable judgment) to have resulted from the willful misconduct or gross negligence of such Indemnified Person. Without limiting the generality of the foregoing, Applicant agrees to indemnify and hold each Indemnified Person harmless for any and all amounts adjudicated or otherwise ordered by any court or other tribunal to be payable by such Indemnified Person in connection with any Bank Guarantees to any beneficiary or its or their respective successors, assigns, heirs, and legal representatives, at any time before or after the expiration of the relevant Bank Guarantee, including the principal amount of any and all amounts drawn under the relevant Bank Guarantee, together with any and all interest thereon and any and all costs and expenses (including reasonable and properly documented out-of-pocket attorney fees) incurred by such Indemnified Person in connection with any such adjudication, or order; except to the extent that any such amount shall be adjudicated or ordered to be payable as a result of the willful misconduct or gross negligence of such Indemnified Person as determined by a court of competent jurisdiction by final and non-appealable judgment.
5.2
Promptly upon the Aval Provider’s written demand, the Applicant shall compensate the Aval Provider for, and hold the Aval Provider harmless from, any loss, cost or expense incurred by it as a result of any failure by Applicant to make payments in Euros of any payment under a Bank Guarantee (or interest due thereon or other Obligations) denominated in Euros on its due date, including any foreign exchange losses.
5.3
Applicant agrees to pay promptly upon the Aval Provider’s written demand from time to time all amounts owing under this section.
6.    No Setoffs or Deductions; Withdrawal from Applicant’s Account
Any and all amounts that may become due and payable to the Aval Provider under this Agreement shall be paid by Applicant in Euros in immediately available funds without defense, setoff, cross-claim, counterclaim or deduction of any kind. Furthermore, Applicant authorizes the Aval Provider to charge any account belonging to Applicant and held with the Aval Provider, or any of the Aval Provider’s affiliates, for any amount when due hereunder.
7.    Conditions Precedent
7.1
The effectiveness of this Agreement is subject to the prior or concurrent satisfaction of each of the conditions precedent set forth in this Section (the date such conditions precedent are satisfied, the “Effective Date”) to the satisfaction of the Aval Provider:
7.1.1
Satisfactory completion of the Aval Provider’s due diligence in connection with the transactions contemplated in the Facility Documents.

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7.1.2
The Aval Provider shall have received this Agreement and other Facility Documents, in form and substance satisfactory to it, executed and delivered by each party thereto (as applicable) and such documentation shall be in full force and effect.
7.1.3
There shall have been delivered to the Aval Provider all of the following:
7.1.3.1
certified or unanimous consent resolutions signed by all shareholders of the Applicant and authorizing Applicant to enter into the Facility Documents to which it is a party and to take all action relative to such Facility Documents; authorizing the Applicant to sign the same; and containing the true signatures of such persons on which the Aval Provider may conclusively rely;
7.1.3.2
copies of the Applicant’s and Parent’s respective Articles of Association as in effect on the Effective Date and an organizational chart of the Parent;
7.1.3.3
a copy of a certificate of good standing issued by competent authorities in Spain and any other applicable jurisdiction (as applicable) (issued within the last thirty (30) days) for the Applicant and Parent;
7.1.3.4
a certificate of incumbency for the Applicant and Parent; and
7.1.3.5
a certificate of a responsible officer of the Applicant and Parent with each of the appropriate attachments.
7.1.4
The Aval Provider shall have received a draft of the authorization request for the Offer, the Offer document (folleto informativo) and the announcement of the Offer.
7.1.5
Delivery of certified, complete copies of all Backstop Agreements and Irrevocable Agreements (including any consents or waivers required in thereunder in connection with the transactions contemplated by the Facility Documents).
7.1.6
Each of the representations and warranties made by the Applicant in Section 15.1 and by any Credit Party pursuant to the Facility Documents, Backstop Agreements and Irrevocable Agreements to which it is a party shall be true and correct in all material respects (except to the extent any such representation and warranty itself is qualified by “materiality,” “Material Adverse Effect” or similar qualifier, in which case, it shall be true and correct in all respects) on and as of the date such representation or warranty is made.
7.1.7
The Aval Provider shall have received a legal opinion of Sullivan & Cromwell LLP, as New York counsel to each of the Credit Parties, and a legal opinion of Uría Menéndez Abogados, S.L.P., as Spanish counsel to each of the Credit Parties, dated

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the Effective Date, covering such matters relating to the Facility Documents, Backstop Agreements, Irrevocable Agreements, the Offer, the Credit Parties and the transactions contemplated hereby as are usual and customary for financings of the type contemplated hereby as the Aval Provider shall reasonably request, in form and substance satisfactory to the Aval Provider.
7.1.8
The Aval Provider shall have received correct and complete copies of the unaudited de-consolidated audited financial statements of the Applicant for the fiscal year ended December 31, 2017, and accompanied by a Responsible Officer’s certificate dated the Effective Date, certifying that such financial statements fairly present in all material respects the financial condition and results of operations of the Applicant for such period and that such financial statements have been prepared in accordance with Spanish GAAP, consistently applied, as at the end of, and for, such period (subject to normal year-end audit adjustments).
7.1.9
The Aval Provider shall have received all documentation and other information requested by the Aval Provider in order to comply with requirements of bank regulatory authorities under applicable “know your customer” laws and Anti-Corruption Law sand Anti-Money Laundering Laws.
7.1.10
No Default or Event of Default shall have occurred and be continuing under this Agreement. No default or event of default (taking into account the proposed issuance of any requested Bank Guarantee) shall have occurred and be continuing with respect to the Cobra Irrevocable Agreement, the Backstop Agreements or any other financing of Parent, TPO or Applicant.
7.1.11
Since December 31, 2017, there shall have been no event or occurrence, individually or in the aggregate, that has resulted in any Material Adverse Effect.
7.2
The obligation of the Aval Provider to issue, amend, renew or extend any Bank Guarantee hereunder is subject to the satisfaction (or waiver by the Aval Provider), of the following conditions precedent:
7.2.1
The Applicant shall provide or cause to be provided to the Aval Provider evidence reasonably satisfactory to the Aval Provider (which may (at the Aval Provider’s reasonable discretion) include delivery of appropriate certificates from responsible officers of the Applicant and Parent), that (a) the Bank Guarantee to be issued and the performance by the Applicant and Parent of their obligations with respect thereto do not conflict with any of the terms, covenants, conditions or provisions of, or constitute a default in respect of, or result in the creation or imposition of, or the obligation to create or impose, any lien (other than the security interests and liens

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created under the Facility Documents or liens permitted under the Facility Documents) on any of their respective properties pursuant to any contractual obligation, together with such additional information regarding the applicable beneficiary as the Aval Provider may reasonably request.
7.2.2
Payment of all fees which are due and payable on the Effective Date under the Facility Documents with respect to the Bank Guarantee.
7.2.3
No Default or Event of Default shall have occurred and be continuing under this Agreement. No default or event of default (taking into account the proposed issuance of any Bank Guarantee) shall have occurred and be continuing with respect to the Cobra Irrevocable Agreement, the Backstop Agreements or any other financing of Parent, TPO or Applicant.
7.2.4
The Facility Documents, Backstop Agreements and the Cobra Irrevocable Agreement shall be in full force and effect and the Offer shall not have been revoked, annulled or rescinded.
8.    Default
8.1
Should any of the following occur (each, an “Event of Default”):
8.1.1
Applicant defaults in respect of any payment due to the Aval Provider or to any of the Aval Provider’s subsidiaries or affiliates, whether such payment is due under this Agreement, in respect of any Bank Guarantee or otherwise;
8.1.2
Applicant fails to perform or observe any other term or covenant of this Agreement in any material respect and such failure shall not have been remedied or waived within ten (10) Business Days after the earlier of (i) an officer of any Credit Party becoming aware of such failure or (ii) receipt by Applicant of notice from the Aval Provider of such failure;
8.1.3
Applicant fails to pay when due any other indebtedness for borrowed money, and such failure continues for more than the period of grace, if any, granted by the creditor(s) with respect to such indebtedness, or any other party to such indebtedness accelerates the maturity of any amount owing in respect thereof as a result of a default with respect to such indebtedness;
8.1.4
any representation or warranty made by Applicant, Parent or Brookfield Asset Management Inc. in any Facility Document or in any certificate or other document delivered in connection with any Facility Document is untrue in any material respect as of the date made;

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8.1.5
any “Event of Default” shall have occurred and be continuing under any Backstop Agreement; or any Credit Party shall have defaulted with respect to its obligations under the Cobra Irrevocable Agreement and such failure continues for more than the period of grace, if any, provided with respect thereto;
8.1.6
the Offer is withdrawn or cancelled;
8.1.7
any Backstop Agreement or the Cobra Irrevocable Agreement shall cease, for any reason, to be in full force and effect (other than in accordance with its terms following payment and performance in full of all obligations thereunder (other than contingent indemnity and similar obligations which by their express terms survive termination thereof for which no claim has been made);
8.1.8
any Backstop Agreement or the Cobra Irrevocable Agreement is declared unenforceable by a Governmental Authority having jurisdiction over any party thereto or the subject matter thereof or is otherwise not in full force and effect (other than in accordance with its terms following payment and performance in full of all obligations thereunder (other than contingent indemnity and similar obligations which by their express terms survive termination thereof for which no claim has been made); or
8.1.9
any Credit Party shall challenge the enforceability of any Facility Document or shall assert in writing, or engage in any action or inaction based on any such assertion, that any provision of any of the Facility Documents has terminated or ceased to be or otherwise is not valid, binding and enforceable in accordance with its terms;
8.1.10
any final judgment or judgments for the payment of money (to the extent not paid or to the extent not covered by insurance as to which the relevant insurance company has acknowledged coverage) aggregating in excess of $10 million is or are outstanding against Applicant and any one of such judgments has remained unpaid, unvacated, unbonded, or unstayed by appeal or otherwise for a period of sixty days from the date of its entry;
8.1.11
Applicant makes an assignment for the benefit of creditors, or admits in writing Applicant’s inability to pay Applicant’s debts as they become due, or commences a voluntary case under any applicable bankruptcy, insolvency or other similar law, or files any petition or answer seeking for the Applicant any reorganization, arrangement, composition, readjustment, liquidation, dissolution or similar relief under any present or future statute, law or regulation relating to creditors’ rights;
8.1.12
within sixty days after the commencement of an action against Applicant seeking any reorganization, arrangement, composition, readjustment, liquidation,

16


dissolution or similar relief under any present or future statute, law or regulation, such action has not been dismissed or all orders or proceedings thereunder affecting Applicant’s operations or business stayed;
8.1.13
any actual or threatened seizure, vesting or intervention by or under authority of a government by which Applicant’s management is displaced or its authority or control of its business is curtailed;
8.1.14
the attachment or restraint of any funds or other property which may be in, or come into, the Aval Provider’s possession or control or of any third party acting on the Aval Provider’s behalf or for Applicant’s account or benefit, or the issuance of any order of any court or other legal process against the same;
8.1.15
any entity or authority or department or body pertaining to the Office of Foreign Assets Control (OFAC) of the US Department of the Treasury, United Nations, European Union or to any other organization or entity to which Spain is subject or obliged to comply with its sanctions in relation to money laundering and financing of terrorism has initiated (or informed the Credit Parties that it will initiate) any sanction, regulatory or other proceeding against any of the Credit Parties which, individually or in the aggregate, is reasonably likely to result in a Material Adverse Effect;
8.1.16
any event causing a Material Adverse Effect occurs;
8.1.17
Applicant consolidates or merges with or into any other entity, or transfers its property as an entirety or substantially as an entirety, unless:
8.1.17.1
the entity (whether Applicant or another entity) formed by or surviving any such consolidation or merger, or to which such transfer shall have been made, shall not be in default under any of the terms, covenants and conditions of this Agreement;
8.1.17.2
the entity (if other than Applicant) formed by or surviving any such consolidation or merger, or to which such transfer shall have been made, shall be a single (x) corporation or limited liability company organized under the laws of the United States of America or any State thereof or the District of Columbia or (y) sociedad anónima or sociedad limitada organized under the laws of the Kingdom of Spain; and
8.1.17.3
the entity (if other than Applicant) formed by or surviving any such consolidation or merger, or to which such transfer shall have been made, shall have assumed in writing the payment of all of Obligations under this

17


Agreement and performance of all of the terms, covenants and conditions of this Agreement;
8.1.18
a Change of Control shall have occurred; or
8.1.19
Parent or Brookfield Asset Management Inc. fails to (a) perform its obligations under the Backstop Agreements to which it is a party with respect to the Applicant’s obligations under Sections 15.3.9 and 15.3.10.1 of this Agreement) or (b) perform or observe any other term or covenant of any Facility Document to which it is a party in any material respect and such failure shall not have been remedied or waived within three (3) Business Days after the earlier of (i) an officer of Parent becoming aware of such failure or (ii) receipt by Applicant of notice from the Aval Provider of such failure;
then the drawn and undrawn amount of the Bank Guarantee as well as any other Obligations hereunder, whether or not matured or contingent, shall, at the Aval Provider’s option, become due and payable immediately without presentment, demand, protest or notice of any kind, all of which are hereby expressly waived by Applicant; provided, however, that upon the occurrence of any Event of Default described in 8.1.11 and 8.1.12 above, the face amount of the Bank Guarantee as well as all other Obligations hereunder, whether or not matured or contingent, shall automatically become due and payable without presentment, demand, protest or notice of any kind, all of which Applicant hereby expressly waives.
8.2
In furtherance, and not in limitation, of the foregoing, upon the occurrence of any Event of Default Applicant shall, upon the Aval Provider’s written demand, deposit Euros in an amount equal to the entire amount which has not been drawn under the Bank Guarantee into a special cash collateral account, designated by the Aval Provider and over which the Aval Provider shall have exclusive right of withdrawal, which shall be charged to reimburse the Aval Provider for amounts paid by the Aval Provider and drawn under a Bank Guarantee. Furthermore, in the case of an Event of Default specified in 8.1.1 the Aval Provider may, in the Aval Provider’s discretion, setoff amounts due and payable to Aval Provider under this Agreement or any Bank Guarantee by any available funds then held by the Aval Provider for Applicant’s account. For the avoidance of doubt, the Aval Provider’s rights under this Section are cumulative and in addition to other rights and remedies which Applicant may have under this Agreement or under applicable law.
9.    RESERVED

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10.    Waiver of Rights; Amendments
No delay on the Aval Provider’s part in the exercise of any right or remedy shall operate as a waiver thereof, and no single or partial exercise by the Aval Provider of any right or remedy shall preclude other or further exercise thereof or the exercise of any other right or remedy. The Aval Provider shall not be deemed to have waived any of the Aval Provider’s rights hereunder unless the Aval Provider or the Aval Provider’s duly authorized agent shall have signed such waiver in writing. No such waiver, unless expressly stated therein, shall be effective as to any transaction which occurs subsequent to the date of such waiver, or as to any continuance of a breach after such waiver. This Agreement shall not be altered, modified, or amended without the prior written consent of the parties hereto.
11.    Extensions, Increases and Modifications
The Aval Provider shall have no obligation to issue, amend, renew, extend or replace any Bank Guarantee hereunder. A request Applicant makes for any amendment, renewal or extension of a Bank Guarantee thereof shall be reviewed by the Aval Provider and the decision to issue, amend, renew or extend shall be made by the Aval Provider in the Aval Provider’s sole discretion. In the event of any extension of the maturity or time for the Bank Guarantee, or any other modification of the terms of a Bank Guarantee, at Applicant’s request or in the event of any increase in the Stated Amount at Applicant’s request, this Agreement shall be binding upon Applicant with regard to such increased amount or otherwise modified, to documents, and property covered thereby, and to any action taken by the Aval Provider or any of the Aval Provider’s correspondents in accordance with such extension, increase or other modification.
12.    No Liability for Certain Actions; Independence
12.1
Without limiting any other provision of this Agreement, Applicant agrees that the Aval Provider and their respective branches, affiliates and correspondents shall not be liable or responsible in any respect for, and Applicant’s reimbursement obligations hereunder shall not be affected by:
12.1.1
the use which may be made of any Bank Guarantee or for any act of or omissions of the beneficiaries under any Bank Guarantee;
12.1.2
the validity, sufficiency, or genuineness of any instructions, oral or written, or any documents which the Aval Provider has determined in good faith to comply on their face with the terms of the relevant Bank Guarantee, even if such documents should in fact prove to be in any or all respects invalid, fraudulent, or forged;

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12.1.3
errors, omissions, interruptions or delays in transmission or delivery of any messages or advices from Applicant or the beneficiaries, however sent and whether or not in code or cipher;
12.1.4
the Aval Provider’s refusal to pay or honor draft requests under any Bank Guarantee because of any applicable law, decree or edict of any Governmental Authority now or hereafter in force;
12.1.5
the identity or authority of any signer or the form, accuracy, genuineness, falsification or legal effect of any draft, certificate or other document appearing on its face:
12.1.5.1
substantially to comply with the terms and conditions of a Bank Guarantee;
12.1.5.2
to be signed or presented by or issued to any successor of the beneficiary or any other Person in whose name a Bank Guarantee requires or authorizes that any draft, certificate or other document be signed, presented or issued, including any administrator, executor, personal representative, trustee in bankruptcy, debtor in possession, liquidator, receiver, or successor by merger or consolidation, or any other Person purporting to act as the representative of or in place of any of the foregoing; or
12.1.5.3
to have been signed, presented or issued after a change of name of the beneficiary,
12.1.6
any requirement stated in or Bank Guarantee that any draft, certificate or other document be presented at a particular hour or place and any discrepancies that do not reduce the value of the beneficiary’s performance to Applicant in any transaction underlying any Bank Guarantee;
12.1.7
Aval Provider’s acceptance as a “draft” of any written or electronic demand or other request for payment under any Bank Guarantee, even if such demand or other request is not in the form of a negotiable instrument;
12.1.8
the effectiveness or suitability of any Bank Guarantee for Applicant’s purpose;
12.1.9
any consequential or special damages, or for any damages resulting from any change in the value of any foreign currency, services or goods or other property covered by any Bank Guarantee;

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12.1.10
the Aval Provider’s assertion or waiver of application of any applicable provision of Spanish law primarily benefiting bank issuers;
12.1.11
Aval Provider’s honor of a previously dishonored presentation under any Bank Guarantee, whether pursuant to court order, to settle or compromise any claim that it wrongfully dishonored or otherwise, and the Aval Provider shall be entitled to reimbursement to the same extent as if it had initially honored said presentation plus reimbursement of any interest paid by it;
12.1.12
Aval Provider’s disregard of any non-documentary conditions stated in any Bank Guarantee; and
12.1.13
Aval Provider’s payment to any nominated bank (or nominated person (in either case as designated or permitted by the terms of any Bank Guarantee) claiming that it rightfully honored under the laws, customs or practice of the place where it is located, except to the extent that any such item, action or omission in each of 12.1.1 through 12.1.13 above is found by a court of competent jurisdiction (in a final and non-appealable judgment) to have resulted from the willful misconduct or gross negligence of the Aval Provider or their respective branches, affiliates and correspondents. None of the foregoing shall affect, impair or prevent the vesting of any of the Aval Provider’s rights or powers hereunder or Applicant’s reimbursement obligations hereunder except to the extent that any of the foregoing is found by a court of competent jurisdiction (in a final and non-appealable judgment) to have resulted from the willful misconduct or gross negligence of the Aval Provider or their respective branches, affiliates and correspondents. Aval Provider and their respective branches, affiliates and correspondents will not be regarded as the drafter of any Bank Guarantee regardless of any assistance that the Aval Provider may, in the Aval Provider’s discretion, provide to the Applicant in preparing the text of any Bank Guarantee or amendments thereto. For the avoidance of doubt, the Aval Provider is authorized (but not obligated) to accept and rely on instructions received by facsimile transmission or e-mail that the Aval Provider believes in good faith to have been given by a Person authorized to give instructions on the Applicant’s behalf. The Aval Provider shall incur no liability to the Applicant or any other Person as a result of any act or omission on the Aval Provider’s part in accordance with instructions on which the Aval Provider is authorized to rely, nor for any failure or refusal on the Aval Provider’s part to accept instructions by facsimile transmission or e-mail that are not confirmed or authenticated to the Aval Provider’s satisfaction.
12.2
Applicant acknowledges that Aval Provider’s rights and obligations under a Bank Guarantee are independent of the existence, performance or nonperformance of any contract or

21


arrangement underlying a Bank Guarantee, including contracts or arrangements between the Aval Provider and Applicant and between Applicant and the beneficiary of a Bank Guarantee. Aval Provider shall have no duty to notify Applicant of Aval Provider’s receipt of a demand or a draft, certificate or other document presented under a bank Guarantee or of Aval Provider’s decision to honor such demand. Aval Provider may, without incurring any liability to Applicant or impairing Aval Provider’s entitlement to reimbursement under this Agreement, honor a demand under a Bank Guarantee despite notice from Applicant of, and without any duty to inquire into, any defense to payment or any adverse claims or other rights against the beneficiary of a Bank Guarantee or any other Person. Aval Provider shall have no duty to request or require the presentation of any document, including any default certificate, not required to be presented under the terms and conditions of a Bank Guarantee. Aval Provider shall have no duty to seek any waiver of discrepancies from Applicant, nor any duty to grant any waiver of discrepancies that Applicant approves or requests.
13.    No Violation of Law
Applicant hereby represents and warrants that none of the execution, delivery or performance of this Agreement or any other Facility Document by Applicant or Parent, nor the request for any issuance of, or amendment to, a Bank Guarantee will violate or contravene any applicable law or regulation. If Applicant’s obligations under this Agreement should be terminated or revoked by operation of law, Applicant will indemnify and save the Aval Provider harmless from any loss (including reasonable out of pocket expenses) that may be incurred by the Aval Provider in acting hereunder prior to such termination or revocation and the maturity or payment of all payments under the Bank Guarantee and this Agreement.
14.    Obligations Absolute
14.1
Applicant’s Obligations under this Agreement are absolute, unconditional and irrevocable, and shall be paid (or performed, as the case may be) strictly in accordance with the terms of this Agreement, under all circumstances whatsoever, including the following circumstances:
14.1.1
the existence of any claim, set-off, defense or other right which Applicant may have at any time against Aval Provider or any Person, whether in connection with this Agreement, any Bank Guarantee or any unrelated transaction;
14.1.2
any draft, statement, certificate or any other document presented under any Bank Guarantee proving to be forged, fraudulent, incorrect, insufficient or invalid in any respect or any statement therein being untrue or inaccurate in any respect whatsoever;

22


14.1.3
any lack of validity or enforceability of this Agreement, a Bank Guarantee or any other agreement, application, amendment, guaranty, document, or instrument relating thereto;
14.1.4
any change in the time, manner or place of payment of or in any other term of all or any of Applicant’s Obligations hereunder or the obligations of any Person that guarantees or otherwise provides support for any of Applicant’s Obligations hereunder;
14.1.5
any exchange, release or non-perfection of any collateral or release or amendment or waiver of or consent to depart from the terms of any guarantee or security agreement, for all or any of Applicant’s Obligations hereunder;
14.1.6
the issuance of a Bank Guarantee (or any amendment thereto) in a form other than substantially as requested by Applicant, unless the Aval Provider receives written notice from Applicant of such error within three (3) Business Days after Applicant shall have received a copy of such Bank Guarantee (or amendment thereto);
14.1.7
Aval Provider’s decision not to issue an amendment to a Bank Guarantee as requested by Applicant;
14.1.8
payment by Aval Provider under a Bank Guarantee against presentation of a draft or other document that does not comply with the terms and conditions of a Bank Guarantee (as applicable) unless the Aval Provider receives written notice from Applicant of such discrepancy within three (3) Business Days following Applicant’s receipt of such draft or other document; and
14.1.9
any action or inaction taken or suffered by Aval Provider or any of their respective affiliates or correspondents in connection with a Bank Guarantee or any relevant draft, certificate or other document, if taken in Good Faith and in conformity with applicable Spanish laws, regulations and practice.
15.    Representations, Warranties and Covenants
15.1
Representations and Warranties
15.1.1
Applicant represents and warrants to the Aval Provider that:
15.1.1.1
Each Credit Party is organized, validly existing and in good standing under the laws of its applicable jurisdiction of organization.
15.1.1.2
The Applicant:

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(a)
has the power and authority, and the legal right, to conduct the business in which it is currently engaged;
(b)
is in compliance with all material requirements of applicable law.
15.1.1.3
Each Credit Party has the power and authority, and the legal right, to make, deliver and perform the Facility Documents to which it is a party and, with respect to the Applicant, to obtain extensions of credit hereunder. Each Credit Party has taken all necessary organizational action to authorize the execution, delivery and performance of the Facility Documents to which it or the Applicant is a party and to authorize the extensions of credit to the Applicant on the terms and conditions of this Agreement. No consent or authorization of, filing with, notice to or other act by or in respect of, any Governmental Authority or any other Person is required in connection with the transactions contemplated hereby and the extensions of credit hereunder or with the execution, delivery, performance, validity or enforceability of this Agreement of the other Facility Documents. Each Credit Party has duly executed and delivered each Facility Document to which it is a party. This Agreement constitutes, and each other Facility Document upon execution will constitute, a legal, valid and binding obligation of each Credit Party party thereto, enforceable against each such Credit Party in accordance with its terms, except as enforceability may be limited by applicable bankruptcy, insolvency, reorganization, moratorium or similar laws affecting the enforcement of creditors’ rights generally and by general equitable principles (whether enforcement is sought by proceedings in equity or at law).
15.1.1.4
The execution, delivery and performance of this Agreement and the issuance of the Bank Guarantee will not violate any law, any provision of the certificate of formation (escritura de constitución), articles of association (estatutos sociales) or other organizational documents, of Applicant or violate any contractual obligation of any Credit Party, and will not result in, or require, the creation or imposition of any lien on any Credit Party’s respective properties or revenues pursuant to any such requirement of law or any such contractual obligation except, in each case (other than the Backstop Agreements and Cobra Irrevocable Agreement) where such violations could not (individually or in the aggregate) reasonably be expected to have a Material Adverse Effect.

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15.1.1.5
No default or event of default exists or, after giving effect to any draw, will exist, under the Cobra Irrevocable Agreement, any Backstop Agreement or any other Facility Document.
15.1.1.6
No Default or Event of Default exists or, after giving effect to any draw, will exist, under this Agreement.
15.1.1.7
On the Effective Date, the Parent and its subsidiaries are, on a consolidated basis, and after giving effect to the extensions of credit made hereunder will be, solvent.
15.1.1.8
The full legal name of the Applicant is TERP Spanish HoldCo, S.L.; and the Applicant is a sociedad limitada organized under the laws of the Kingdom of Spain.
15.1.1.9
The Applicant (a) has not conducted any business other than the business contemplated by the Articles of Association and (b) has no outstanding contractual obligations other than those (i) set forth in the Facility Documents or (ii) allowed pursuant to its Articles of Association and the Facility Documents and related to the incorporation and ongoing corporate matters of the Applicant, its acquisition by NSF or the Offer.
15.1.1.10
There are no pending, nor has any Credit Party received written notice regarding, threatened actions or proceedings of any kind, including actions or proceedings of or before any Governmental Authority, to which a Credit Party or any subsidiary or affiliate thereof is a party or is subject, or by which any of its respective properties are bound that would reasonably be expected to result in a Material Adverse Effect.
15.1.1.11
Each financial statement of the Applicant, delivered to the Aval Provider, has been prepared in conformity with Spanish GAAP and fairly presents, in all material respects, the financial position of the Applicant described in such financial statements as at the respective dates thereof and the results of operations and the changes in cash flows of the Applicant described therein for each of the periods then ended except as otherwise noted therein and subject, in the case of any such unaudited financial statements, to changes resulting from audit and normal year-end adjustments. As of December 31, 2017, the Applicant did not have any material Indebtedness or material guarantees other than as referenced, reflected or provided for in such audited financial

25


statements (or in the notes thereto) in accordance with customary auditing standards.
15.1.1.12
All written information (other than any “forward looking statements”) (the “Information”) concerning the Credit Parties and the transactions contemplated hereby prepared by, or as directed by, the Credit Parties or any of their Affiliates and made available to the Aval Provider on or prior to the Effective Date in connection with the transactions contemplated hereby, when taken as a whole, was true and correct in all material respects as of the date such Information was furnished to the Aval Provider and as of the Effective Date and (as of the date such Information was furnished to the Aval Provider and as of the Effective Date) did not contain any untrue statement of a material fact or omit to state a material fact necessary in order to make the statements contained therein (taken as a whole) not materially misleading in light of the circumstances under which such statements were made.
15.1.1.13
The Applicant (a) has timely filed or caused to be timely filed all material tax returns required to have been filed by them and (b) have timely paid or caused to be paid all material taxes due and payable by them, except any taxes or assessments that are being contested in good faith by appropriate proceedings for which appropriate reserves have been established in accordance with Spanish GAAP. No tax liens have been filed with respect to the assets of the Applicant.
15.1.1.14
None of the Credit Parties nor any of their respective properties or assets is in violation of (nor will the continued operation of its properties and assets as currently conducted violate):
(a)
its organizational documents; or
(b)
any currently applicable laws, except (solely with respect to this clause) any violation or non-compliance that would not reasonably be expected to result in a Material Adverse Effect. None of the Credit Parties are in default under or with respect to any of their respective material contractual obligations in any respect that would reasonably be expected to result in a Material Adverse Effect.

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15.1.1.15
None of the Credit Parties has engaged in any unfair labor practice that would reasonably be expected, individually or in the aggregate, to result in a Material Adverse Effect.
15.1.1.16
The Applicant does not have any employees in the United States and is not subject to the jurisdiction of or any regulations related to the Employee Retirement Income Security Act of 1974, as amended.
15.1.1.17
The activities of the Credit Parties and each subsidiary thereof are in compliance with all, and have not violated any, environmental laws, other than as would not reasonably be expected to, individually or in the aggregate, result in a Material Adverse Effect.
15.1.1.18
None of the Credit Parties or any subsidiary thereof has received any written notice that any aspect of the business or the operations or facilities (whether owned or leased) of any Credit Party is in violation of, or in noncompliance with, any environmental law or is subject to liability under any environmental law, that would reasonably be expected to, individually or in the aggregate, result in a Material Adverse Effect.
15.1.1.19
The Parent owns and controls, directly or indirectly, more than a majority of the voting power and economic interests in the Applicant. All of the issued and outstanding membership interests of the Applicant have been duly authorized and issued and are fully paid and non-assessable. For purposes of this paragraph, “control” of a Person means the power, directly or indirectly, either to:
(a)
vote the specified percentage of the securities having ordinary voting power for the election of directors (or persons performing similar functions) of such Person; or
(b)
direct or cause the direction of the management and policies of such Person, whether by contract or otherwise.
15.1.1.20
The operations of each member of the Group are and have been conducted at all times in compliance with all applicable Anti-Money Laundering Laws and Anti-Corruption Laws and no action, suit or proceeding by or before any Governmental Authority or any arbitrator involving a member of the Group with respect to Anti-Money Laundering Laws and/or Anti-Corruption Laws is pending and no such actions, suits or proceedings are threatened or contemplated.

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15.1.2
Each request by Applicant for an amendment to this Agreement or for the issuance of a Bank Guarantee or for any amendment to a Bank Guarantee shall constitute Applicant’s representation and warranty that the foregoing statements are true and correct as if made on the date of such request.
15.2
Information Covenants
Applicant shall furnish to the Aval Provider:
15.2.1
as soon as practicable and in any event within sixty (60) days after the end of each quarterly period in each fiscal year, which is not the end of a fiscal year, Parent’s unaudited consolidated profit and loss statements and reconciliation of retained earnings statements for the period from the beginning of the current fiscal year to the end of such quarterly period, and Parent’s consolidated balance sheet as at the end of such quarterly period, setting forth in each case in comparative form corresponding consolidated figures from the corresponding period in the immediately preceding fiscal year, all in reasonable detail and prepared in accordance with U.S. GAAP and certified by Parent’s chief financial officer, treasurer, assistant treasurer or controller (“Responsible Officer”) subject to changes resulting from year-end adjustments that such financial statements fairly present in all material respects the financial condition and results of operations for such period; provided that the filing by Parent of its quarterly reports and consolidated financial statements on either the U.S. Securities and Exchange Commission’s EDGAR filing system or a publicly accessible website will be deemed to satisfy the obligations of Applicant under this Section 15.2.1;
15.2.2
promptly upon obtaining knowledge of the occurrence of any Event of Default pursuant to Section 8 (Default) or any event which with notice or lapse of time or both would constitute an Event of Default pursuant to Section 8 (Default), notify the Aval Provider thereof in writing, specifying the nature thereof and the action Applicant proposes to take with respect thereto;
15.2.3
prompt written notice of any event or development that Applicant believes would reasonably be expected to have a Material Adverse Effect;
15.2.4
with reasonable promptness, any other financial data relating to the performance of this Agreement and Applicant’s affairs that the Aval Provider may from time to time reasonably request; and
15.2.5
by the last Business Day of each month, provide a Responsible Officer’s certificate certifying the available amounts to be drawn under each of the Backstop Agreements, and that no default or event of default under such Backstop

28


Agreements exists and that, to the knowledge of such Responsible Officer, such amounts are available to be drawn.
15.3
Affirmative Covenants
Applicant will:
15.3.1
comply with all New York, United States and Spanish and European laws, regulations and rules (including all tax, Anti-Money Laundering Laws, Anti-Corruption Laws, sanctions, foreign exchange and foreign assets control regulations and other trade-related regulations) and practice now or later applicable to Bank Guarantees, transactions related to a Bank Guarantees, or Applicant’s execution, delivery and performance under this Agreement and deliver to the Aval Provider, upon reasonable request, satisfactory evidence of such compliance;
15.3.2
conduct the Offer at all times in compliance with the terms and conditions of the Offer Documents.
15.3.3
permit the Aval Provider to inspect Applicant’s books and records on reasonable notice;
15.3.4
preserve and maintain Applicant’s existence, rights, franchises and business operations;
15.3.5
except as otherwise expressly permitted under the Facility Documents:
15.3.5.1
maintain and preserve its existence as a sociedad limitada and all material rights, privileges and franchises necessary or desirable in the normal conduct of its business; and
15.3.5.2
perform (to the extent not excused by force majeure events or the non-performance of the other party), all of its material contractual obligations under the Facility Documents, the Cobra Irrevocable Agreement and all other agreements and contracts by which it is bound;
15.3.6
maintain adequate books, accounts and records and prepare all financial statements required under the Facility Documents in accordance with Spanish GAAP and in compliance with the regulations of any Governmental Authority having jurisdiction thereof, and permit each of the employees or agents of the Aval Provider during business hours and upon reasonable prior notice to inspect all Applicant’s and Applicant’s subsidiaries’ properties, to examine or audit all of Applicant’s books, accounts and records and make copies and memoranda thereof;

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15.3.7
file, as and when due, all tax returns and shall pay, or cause to be paid, as and when due and prior to delinquency, all taxes, assessments and governmental charges of any kind that may at any time be lawfully assessed or levied against or with respect to Applicant; provided, that Applicant may contest in good faith any such taxes, assessments and other charges and, in such event, may permit the taxes, assessments or other charges so contested to remain unpaid during any period, including appeals, when Applicant is in good faith contesting the same, so long as:
15.3.7.1
reasonable reserves have been established in an amount sufficient to pay any such taxes, assessments or other charges, accrued interest thereon and potential penalties or other costs relating thereto, or other adequate provision for the payment thereof shall have been made;
15.3.7.2
enforcement of the contested tax, assessment or other charge is effectively stayed for the entire duration of such contest; and
15.3.7.3
any tax, assessment or other charge determined to be due, together with any interest or penalties thereon, is paid when due after resolution of such contest;
15.3.8
at its expense, within such time as may be required by applicable law comply, or cause compliance in all material respects, with all legal requirements applicable to Applicant, except that Applicant may, at its expense, contest by appropriate proceedings conducted in good faith the validity or application of any such legal requirements provided that:
15.3.8.1
none of Aval Provider or any Credit Party would be subject to any criminal liability for failure to comply therewith; and
15.3.8.2
all proceedings to enforce such legal requirements against the Aval Provider, or any Credit Party, shall have been duly and effectively stayed during the entire pendency of such contest;
15.3.9
cause to be maintained at all times, and provide evidence reasonably acceptable to the Aval Provider that availability exists, minimum availability under Backstop Agreements as follows: no less than US$400,000,000 under the Revolver and no less than US$500,000,000 under the Sponsor Line;
15.3.10
if at any time after the Effective Date, the Applicant agrees to limitations on Indebtedness, limitations on liens or financial covenants, in the documentation evidencing any other Indebtedness of the Applicant, any of which are more

30


stringent or restrictive than the limitations or financial covenants in this Agreement, or, with respect to the Natixis Facility, any covenants more favorable to the lender under such facility, then, at the Aval Provider’s option (which may be exercised at any time), this Agreement will be deemed automatically amended so that the Aval Provider also shall benefit from such more stringent or restrictive limitations and financial covenants, or with respect to the Natixis Facility, any such covenants, such that a breach of such more stringent or restrictive limitations and financial covenants or other covenants shall constitute a breach of this Section 15 (Representations, Warranties and Covenants), and this Agreement regardless of any waiver or forbearance granted by the creditors of such other Indebtedness or termination or repayment of any such other Indebtedness. The Applicant agrees to promptly inform the Aval Provider of any such other Indebtedness and to furnish to the Aval Provider a copy of the documentation containing such more stringent or restrictive limitations and financial covenants. The Applicant further agrees to enter into such amendments to this Agreement as reasonably requested by the Aval Provider to conform this Agreement as contemplated by the first sentence of this Section 15.3.10 (it being acknowledged and agreed that the failure to enter into any such amendment shall not limit the effectiveness of the first sentence of this Section 15.3.10);
15.3.10.1
in the event that the Aval Provider shall demand that Applicant fund any cash collateral deposit pursuant to the last paragraph of Section 8 (Defaults),
(a)
promptly (and in any event not more than (x) three (3) Business Days with respect to any drawing described in Section 15.3.10.1(a)(i) below or (y) forty-five (45) days following the applicable demand with respect to any issuance described in Section 15.3.10.1(a)(ii) below) cause Parent to take (and/or cause its applicable subsidiaries, including TPO, as the case may be, to take) the following actions to the extent required to ensure that the Applicant has immediately available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding amount drawn under the Bank Guaranty (together with any other Obligations then payable) and any corresponding collateralization, reimbursement or other obligations due under the Natixis Facility:
(i)
first, cause TPO to submit a request for and draw the maximum amount available to be drawn under the Revolver

31


and/or submit a request for and draw the maximum amount available to be drawn under the Sponsor Line; and
(ii)
second, issue and sell new shares of Class A common stock in Parent for net proceeds in an amount not to exceed US$400 million; and
(b)
promptly (and in any event not more than forty-five (45) days following the disbursement of the proceeds from any such draw or issuance), cause Parent to make or cause to be made (and/or cause its applicable subsidiaries (including TPO), as the case may be, to make or cause to be made) equity contributions to Applicant (utilizing in whole or in part, in its sole discretion, an amount up to the net proceeds resulting from such drawings and/or issuance) to the extent required to ensure that the Applicant has immediately available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding amount drawn under the Bank Guaranty (together with any other Obligations then payable) and any corresponding and any corresponding collateralization, reimbursement or other obligations due under the Natixis Facility; provided that, notwithstanding the foregoing, in any event Applicant shall cause Parent to contribute or cause to be contributed (and/or cause its applicable subsidiaries (including TPO) (as the case may be) to contribute or cause to be contributed) the amounts required to be requested pursuant to Section 15.3.10.1(a)(i) in an amount equal to the lesser of (x) US$900,000,000 and (y) the amount of any demanded cash collateral and (without duplication) outstanding amount drawn under the Bank Guaranty (together with any other Obligations then payable) to Applicant not more than eight (8) Business Days following the disbursement of the proceeds from any such draw or issuance; and
15.3.10.2
on or prior to the third (3rd) Business Day following the Effective Date, pay all fees due and payable pursuant to Section 3 (Payment for Services Rendered), together with all costs and expenses, including legal expenses, of the Aval Provider and any fees payable pursuant to the Bank Guarantee issued on or prior to the third (3rd) Business Day following the Effective Date.

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15.4
Negative Covenant
Applicant will not, and will not permit or authorize any of its subsidiaries to:
15.4.1
directly or indirectly, use, lend, make payments of, contribute or otherwise make available, all or any part of the proceeds of any Bank Guarantee or other transaction(s) contemplated by this Agreement to fund any trade, business or other activities: in any other manner that would reasonably be expected to result in any member of the Group or any Lender being in breach of Anti-Money Laundering Laws, and/or Anti-Corruption Laws (if and to the extent applicable to them);
15.4.2
enter into or become a party to any contracts or agreements not related to ownership of SAY or the transactions contemplated by the Facility Documents;
15.4.3
not to sell, assign, pledge or in whatever form dispose of or encumber any of the SAY shares acquired under the Offer until any amounts due by the Applicant under this Agreement and all of the Applicant’s Obligations hereunder have been fully satisfied;
15.4.4
liquidate, wind-up or dissolve, or sell or lease or otherwise transfer or dispose of all or any substantial part of its property, assets or business or combine, merge or consolidate with or into any other entity, or change its legal form, or implement any material acquisition or purchase of assets from any Person;
15.4.5
except as provided in the Natixis Facility or other Facility Documents, become liable as a surety, guarantor, accommodation endorser or otherwise, for or upon the obligation of any other Person or otherwise create, incur, assume or suffer to exist any contingent obligation;
15.4.6
except as provided in the Santander Facility, this Agreement or the other Facility Documents, incur, create, assume or permit to exist any Indebtedness or any lien on Applicant’s assets or properties;
15.4.7
execute a binding agreement to become a general or limited partner in any partnership, or a member in any limited liability company, sociedad de responsabilidad limitada, sociedad anónima, other company, or a joint venturer in any joint venture or acquire property, create and hold stock or other equity interests in any Person or form or acquire any subsidiaries, in each case (i) other than the Applicant and (ii) not related to ownership of SAY or the transactions contemplated by the Facility Documents;

33


15.4.8
cause, consent to, or permit any termination, amendment, modification, variance or waiver of timely compliance with any terms or conditions of the certificate of formation (escritura de constitución) or any other organizational documents of Applicant;
15.4.9
change its name or its jurisdiction of organization without written notice to the Aval Provider at least thirty days prior to such change, or change its fiscal year;
15.4.10
change the location of its chief executive office or principal place of business without written notice to the Aval Provider within thirty (30) days after such change;
15.4.11
modify or amend, waive or terminate in any manner adverse to the Aval Provider, any of the Backstop Agreements or the Cobra Irrevocable Agreement; or
15.4.12
modify or amend the Natixis Facility without Aval Provider’s prior written consent.
16.    Effectiveness / Assignment
This Agreement shall become effective the Effective Date and shall be binding upon Applicant and Applicant’s successors and assigns. No assignment or other transfer of all or any of the rights of the undersigned hereunder, whether with regard to any property or otherwise, may be made without the Aval Provider’s prior written consent.
17.    Waiver of Immunity
Applicant acknowledges that this Agreement is, and each Bank Guarantee will be, entered into for commercial purposes and, to the extent that Applicant now or later acquires any immunity from jurisdiction of any court or from any legal process with respect to Applicant or Applicant’s property, Applicant now irrevocably waives Applicant’s immunity with respect to Applicant’s Obligations hereunder.
18.    Termination; Surviving Provisions
18.1
If the Offer is withdrawn or cancelled, this Agreement and any Bank Guarantees will be automatically cancelled on the date falling three months after such withdrawal or cancellation or such later date on which all the amounts due by the Applicant under this Agreement and all of Applicant’s Obligations hereunder have been fully satisfied.
18.2
If, as at the date on which settlement of the Offer occurs, the conditions set forth in Article 47 of RD 1066/2007 for the exercise by the Applicant and SAY shareholders of the squeeze-out and sell-out respective rights are satisfied:
18.2.1
any Bank Guarantee will not be cancelled in full; and

34


18.2.2
any cancellation in part will be made following prior consultation of the Aval Provider and Applicant with CNMV and subject to the CNMV’s instructions thereto.
18.3
Restrictive provisions in this Agreement, such as indemnity, tax, immunity and jurisdiction provisions shall survive the termination of this Agreement, expiration of any amounts due by the Applicant under this Agreement and payment of Applicant’s Obligations hereunder. If any guarantee is issued in favor of any bank, Banco Santander’s branch or other entity in support of an undertaking issued by such bank, branch or entity on Applicant’s behalf or request, Applicant shall remain liable under this Agreement (even after expiry of such guarantee) for amounts paid and expenses incurred by the Aval Provider with respect to such guarantee or such undertaking until such time as Aval Provider or such other bank, branch or entity shall have no further liability, under applicable law, in connection with such undertaking.
19.    Notices
19.1
Except as expressly provided to the contrary herein, any communication, notice or demand to be given hereunder shall be duly given if delivered or mailed by certified or registered mail or sent by, fax or email as follows:

35


If to Applicant, at:
TERP Spanish HoldCo, S.L.
 
99 Bishopsgate, London, EC2M 3XD
 
Attention: Ms. Emmanuelle Rouchel
e-mail: ####@brookfield.com

and

TERP Spanish HoldCo, S.L.
21 calle Serrano, 2nd floor, 28001, Madrid, Spain
Attention: Mr. Ricardo Arias
e-mail: ####@brookfield.com

With a copy to:

TerraForm Power, Inc.
7550 Wisconsin Avenue, 9th Floor.
Bethesda, Maryland, 20814
Attention: General Counsel
e-mail: ####@brookfield.com

If to Aval Provider, at:
Banco Santander, S.A.
 
3 Gran Vía de Hortaleza
Edificio Pedreña, planta sótano
 
28033 Madrid, Spain
 
Attention: Mr. Fernando Fernández de Alegría López
Executive Director
 
fax: +34 91 289 12 73
 
 
 
19.2
Applicant agrees that the Aval Provider may act upon email or facsimile instructions which are received by the Aval Provider from Persons purporting to be, or which instructions appear to be, authorized by Applicant. Applicant further agrees to indemnify and hold the Aval Provider harmless from any claims by virtue of the Aval Provider acting upon such email or facsimile instructions as such instructions were understood by the Aval Provider, except to the extent such claims relate to the Aval Provider’s gross negligence or willful misconduct. Aval Provider shall not be liable for any errors in transmission or the illegibility of any emailed or telecopied documents. In the event Applicant sends the Aval Provider a manually signed confirmation of previously sent email, or facsimile instructions, the Aval Provider shall have no duty to compare it against the previous instructions received by the Aval Provider nor shall the Aval Provider have any responsibility should the contents of the written confirmation differ from the email or facsimile instructions acted upon by Aval Provider.

36


20.    Interpretation
20.1
The parties acknowledge and agree that:
20.1.1
each party and its counsel have reviewed the terms and conditions of this Agreement and have contributed to the revision of same;
20.1.2
the normal rule of construction which holds that any ambiguities are resolved against the drafting party, shall not be employed in the interpretation of this Agreement;
20.1.3
the terms and provisions of this Agreement shall be constructed fairly as to both parties hereto and not in favor of or against any party, regardless of which party was generally responsible for the preparation of this Agreement;
20.1.4
the term “including” means “including without limitation”, as used in this Agreement;
20.1.5
if any provision of this Agreement is held illegal or unenforceable, the validity of the remaining provisions shall not be affected;
20.1.6
headings are included only for convenience and are not interpretive;
20.1.7
this Agreement constitutes the entire agreement between the parties concerning the Aval Provider’s issuance of a Bank Guarantee and supersedes all prior agreements governing such issuance;
20.1.8
Applicant may submit an executed Application for a Bank Guarantee in original form, via fax, email attachment or other electronic means and Applicant will be bound by any instructions so given;
20.1.9
delivery of a signed signature page to this Agreement by facsimile transmission or email attachment shall be effective as, and shall constitute physical delivery of, a signed original counterpart of this Agreement;
20.1.10
if this Agreement is signed by two or more persons or entities:
20.1.10.1
each such person or entity shall be deemed an “Applicant” hereunder;
20.1.10.2
each Applicant shall be jointly and severally liable for all the Obligations hereunder; and
20.1.10.3
notices from the Aval Provider in connection with this Agreement or the Bank Guarantee to either Applicant and notices from, or the consent

37


of, either Applicant in connection with this Agreement or the Bank Guarantee shall be sufficient to bind all Applicants;
20.1.11
all references herein and in any other Facility Document to any fees, Bank Guarantees, Stated Amount and other obligations and amounts shall be denominated in Euros, unless expressly provided otherwise; and
20.1.12
the Applicant and Parent shall deliver financial statements and calculate and perform financial and other covenants in Euros.
21.    Multiple Role Disclosure
The Aval Provider and Aval Provider’s affiliates offer a wide range of financial services. Such services are provided internationally to a wide range of customers, some of whom may be Applicant’s counterparties or competitors. Applicant acknowledges and accepts that the Aval Provider and Aval Provider’s affiliates may perform more than one role in relation to a Bank Guarantee, including advising a Bank Guarantee, notwithstanding the selection by Applicant of an additional or alternative advising bank.
22.    Governing Law and Jurisdiction
This Agreement shall be governed and construed in accordance with the laws of Spain. For the purposes of any proceeding, action or suit involving this Agreement, each party hereto hereby expressly submits to the jurisdiction of any court of record of Madrid, and agrees that any order, process or other paper may be served upon either party within or without such court’s jurisdiction by mailing a copy thereof to the affected party at its address (that with respect to the Aval Provider, shall be the address shown on the first page of this Agreement, and with respect to Applicant, shall be the address shown below). Each party waives any claim that such proceeding, action or suit has been brought in an inconvenient forum.



38


Very truly yours,
TERP Spanish HoldCo, S.L.

By: /s/ Ricardo Arias Sainz
 
Name: Ricardo Arias Sainz
 
Title: Joint and Several Director
 




[Signature page to the Agreement for Banco Santander, S.A.’s Guarantee]



Acknowledged and agreed:
Banco Santander, S.A.

By: /s/ Daniel Machuca Reyes   
 
Name: Daniel Machuca Reyes
 
Title: Executive Director
 
By: /s/ Fernando Fernandez de la Alegria   
 
Name: Fernando Fernandez de la Alegria
 
Title: Executive Director
 




[Signature page to the Agreement for Banco Santander, S.A.’s Guarantee]



EXHIBIT I

Form of Bank Guarantee (Spanish Version)
AVAL
[___] (Entidad Avalista), con domicilio social en [___], entidad debidamente registrada en el Registro de Sociedades de [___], con el número [___], representada por [___], mayor de edad, con [documento nacional de identidad / pasaporte] número [___], y [___], mayor de edad, con [documento nacional de identidad / pasaporte], ambos con facultades suficientes para este acto en virtud de [Se incorporarán los detalles del apoderamiento],
AVALA
ante la COMISIÓN NACIONAL DEL MERCADO DE VALORES y en beneficio de los accionistas de la sociedad SAETA YIELD, S.A. que acudan a la oferta pública de adquisición formulada por TERP Spanish Holdco, S.L., con domicilio social en calle Serrano, 21, Madrid, 28001 e inscrita en el Registro Mercantil de Madrid, al tomo 35.995, folio 9, sección 8, hoja M-646.732, inscripción 1ª (el Oferente), sobre las acciones de SAETA YIELD, S.A. (la Oferta), las obligaciones de pago del precio en efectivo asumidas por el Oferente en la Oferta, cuyos términos y condiciones se describen en el folleto explicativo presentado para su registro en la COMISIÓN NACIONAL DEL MERCADO DE VALORES, en cumplimiento de lo dispuesto en el Real Decreto 1066/2007, de 27 de julio, sobre el régimen de las ofertas públicas de adquisición de valores.
La cantidad máxima avalada por la Entidad Avalista es de [___] euros ([___]€). El presente aval se otorga con carácter incondicional, irrevocable y solidario con respecto a las obligaciones de pago del Oferente derivadas de la Oferta y con renuncia expresa a los beneficios de excusión, orden y división.
El pago de las responsabilidades dimanantes de este aval se llevará a efecto en Madrid, a primer requerimiento de SOCIEDAD DE GESTIÓN DE LOS SISTEMAS DE REGISTRO, COMPENSACIÓN Y LIQUIDACIÓN DE VALORES, S.A. UNIPERSONAL (IBERCLEAR) o de la COMISIÓN NACIONAL DEL MERCADO DE VALORES, mediante requerimiento escrito dirigido a la Entidad Avalista en el siguiente domicilio [___]. Recibido el requerimiento de pago correspondiente, la Entidad Avalista procederá a efectuar el pago del importe correspondiente en la cuenta que el requirente haya designado, en el día hábil siguiente al de la recepción de dicho requerimiento. El presente aval permanecerá en vigor hasta el completo cumplimiento de las obligaciones de pago del Oferente derivadas de la Oferta o, en su caso, hasta la fecha en que la Oferta sea retirada, anulada o declarada sin efecto.
Este aval se rige por la ley española. La Entidad Avalista, con renuncia a cualquier otro fuero que pudiera corresponderle, se somete a los tribunales de la ciudad de Madrid para dirimir cualquier disputa o controversia que pudiese surgir en relación con la interpretación, alcance, cumplimiento, efectos y ejecución del presente aval.
El presente Aval ha sido inscrito en el Registro Especial de Avales con el número [___].
En [Lugar], a [día] de [mes] de [año].




[Denominación social de la Entidad Avalista]
 
P.p.

____________________
 
[Nombre]
 
[Cargo]
P.p.

____________________
 
[Nombre]
 
[Cargo]






Form of Bank Guarantee (English translation)
GUARANTEE
[___] (the Guarantor Entity), with registered office at [___], duly registered with the Companies Registry of [___], with number [___], represented by [___], of legal age, with [national identity card number / passport number] [___], and [___] of legal age, with [national identity number / passport number], both with sufficient powers pursuant to [Insert details of relevant powers of attorney].
GUARANTEES
before the COMISIÓN NACIONAL DEL MERCADO DE VALORES and for the benefit of the shareholders of SAETA YIELD, S.A. who accept the takeover offer launched by TERP Spanish Holdco S.L., with registered office at 21 calle Serrano, Madrid, 28001 and duly registered with the Companies Registry of Madrid, at book 35,995, volume 9, section 8, sheet M-646,732, entry 1 (the Bidder), over the shares in SAETA YIELD, S.A. (the Offer), the obligations assumed by the Bidder regarding the payment in cash of the consideration of the Offer, which terms and conditions are described in the Offer prospectus which has been filed for registration with the COMISIÓN NACIONAL DEL MERCADO DE VALORES, in accordance with the provisions of Royal Decree 1066/2007, of July 27, on public takeover bids for securities.
The maximum amount guaranteed by the Guarantor Entity is Euro [___] (€[___]).
This guarantee unconditionally, irrevocably and jointly and severally guarantees the payment obligations of the Bidder arising under the Offer, with express waiver of the benefits of ranking, priority and separation (excusión, orden y división).
Payment of the amounts payable under this guarantee will be made in Madrid on first demand for payment made by SOCIEDAD DE GESTIÓN DE LOS SISTEMAS DE REGISTRO, COMPENSACIÓN Y LIQUIDACIÓN DE VALORES, S.A. UNIPERSONAL (IBERCLEAR) or by the COMISIÓN NACIONAL DEL MERCADO DE VALORES, made in writing and addressed to the Guarantor Entity at the following address: [___]. Once the demand for payment is received, the Guarantor Entity will make the corresponding payment to the account indicated on the demand on the Business Day following receipt of the relevant payment demand.
This guarantee will remain in full force and effect until the payment obligations of the Bidder arising under the Offer have been discharged in full or, if applicable, until the date the Offer is withdrawn, annulled or declared as without effect.
This guarantee is governed by Spanish law. The Guarantor Entity, waiving the right to any other jurisdiction which it may be entitled to, submits to the jurisdiction of the courts of the city of Madrid to resolve any dispute or disagreement that could arise in relation to the interpretation, scope, performance, effect and enforcement of this guarantee.




This guarantee has been registered on the Special Registry of Guarantees with number [___].
In [Place], on [day] [Month] [year].

[Registered name of the Guarantor Entity]
 
By

___________________
 
[Name]
 
[Position]
By

___________________
 
[Name]
 
[Position]




Exhibit
EXECUTION


Exhibit 10.22
March 6, 2018
TERRAFORM POWER, INC.
7550 Wisconsin Avenue
Bethesda, Maryland 20814
United States of America
Ladies and Gentlemen,
Reference is made to that certain Agreement for Bank Guarantee, dated as of March 6, 2018 (as amended, modified, supplemented and in effect from time to time, the “Bank Guarantee” or “Bank Guarantee Agreement”), entered into concurrently with the execution and delivery of this letter agreement (this “Agreement”), by TERP Spanish HoldCo, S.L. (the “Applicant”) and Banco Santander, S.A. (the “Aval Provider”), pursuant to which the Aval Provider has agreed to guarantee the obligations of the Applicant in respect of the full payment of the cash consideration under the Applicant’s takeover bid (the “Offer”) which has been launched for all of the outstanding shares of Saeta Yield, S.A. (“SAY”) vis-à-vis the Comisión Nacional del Mercado de Valores or “Sociedad de Gestión de los Sistemas de Registro, Compensación y Liquidación de Valores, S.A. Unipersonal”, as the entity responsible for the Spanish clearing and settlement system, and for the benefit of the SAY shareholders accepting the Offer, all in accordance with Royal Decree 1066/2007, of 27 July, on the rules applicable to public takeover bids for securities (Real Decreto 1066/2007, de 27 de julio, sobre el régimen de las ofertas públicas de adquisición de valores –“RD 1066/2007”–). Unless otherwise specified herein, all capitalized terms used and not otherwise defined herein will have the meanings ascribed to them in the Bank Guarantee Agreement.
By its signature below, Terraform Power, Inc. (the “Parent”) hereby: (i) acknowledges and confirms that (a) it is a condition precedent to the effectiveness of the Bank Guarantee Agreement that the Parent shall have executed and delivered this Agreement, (b) Parent has agreed to take (and/or cause TPO to take) any actions necessary to cause or permit the Applicant to comply with its obligations under Sections 8.2, 15.3.9 and 15.3.10.1 of the Bank Guarantee Agreement in order to finance the funding of any cash collateral account pursuant to Section 8.2 of the Bank Guarantee Agreement (“Cash Collateral Deposit”) and the repayment of any outstanding Draft and (c) each of the Credit Parties will derive economic benefit from the Bank Guarantee; and (ii) hereby agrees with the Aval Provider as follows:




1.
Parent hereby represents and warrants to and in favor of the Aval Provider, as of the date hereof, as follows (which representations and warranties shall survive the execution and delivery of this Agreement):
(a)
Parent (i) is familiar with, and has independently reviewed, books and records regarding the financial condition of other Credit Parties and (ii) has reviewed and is familiar with the Facility Documents and other documents relating thereto that are material to its obligations hereunder;
(b)
Parent directly or indirectly owns one hundred percent (100%) of the equity interests in each of TPO, NSF and the Applicant, excluding any incentive distribution rights in TPO (as in effect on the date hereof);
(c)
Parent is not executing this Agreement with any intention to hinder, delay or defraud any of its or the other Credit Parties creditors;
(d)
Parent (i) is duly incorporated, validly existing and in good standing under the laws of the State of Delaware and (ii) is duly qualified to do business and in good standing in each jurisdiction in which such qualification is necessary to execute, deliver and perform this Agreement;
(e)
Parent has the corporate power and authority to execute, deliver and perform this Agreement and to take all corporate action as may be necessary to complete the transactions contemplated hereunder. The Parent has taken all necessary action to authorize the execution, delivery and performance of this Agreement and to complete the transactions contemplated hereby. No consent or authorization of, filing with, or other act by or in respect of any other Person or Governmental Authority is required in connection with the execution, delivery or performance by the Parent, or the validity or enforceability as to the Parent, of this Agreement, except such consents, authorizations, filings or other acts as have already been obtained or made. This Agreement has been duly executed and delivered by the Parent and constitutes a legal, valid and binding obligation of the Parent enforceable against it in accordance with its terms, except as enforceability may be limited by applicable bankruptcy, insolvency, reorganization, moratorium or similar laws affecting the right of creditors generally and by general principles of equity;
(f)
The execution, delivery and performance by the Parent of this Agreement, and the consummation of the transactions contemplated hereby (including the performance by the Parent of any of its obligations hereunder), does not violate any law, any provision of the certificate of formation, operating agreement or other organizational documents of any Credit Party or violate any contractual obligation of any Credit Party, and will not result in, or require, the creation or imposition of any lien on any of their respective properties or revenues pursuant to any such requirement of law or any such contractual obligation, except, in each case (other than the Backstop Agreements and Cobra Irrevocable Agreement) where such violations could not (individually or in the aggregate) reasonably be expected to have a Material Adverse Effect;

2


(g)
Parent is in compliance with all requirements of applicable law, except to the extent any non-compliance could not reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder;
(h)
No litigation or proceeding of or before any arbitrator or Governmental Authority is pending or, to the Parent’s knowledge, threatened against or affecting the Parent or any of its properties or assets or the transactions contemplated by this Agreement and the other Facility Documents in each case which, if adversely determined, would reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder;
(i)
Each financial statement and financial report of Parent heretofore delivered to the Aval Provider pursuant to the Facility Documents fairly represents, in all material respects, the financial position of Parent and its consolidated subsidiaries as at the respective dates thereof and the results of operations and the changes in cash flows of Parent and its consolidated subsidiaries for each of the periods then ended, except as otherwise noted therein and subject, in the case of any such unaudited financial statements, to changes resulting from audit and normal year-end adjustments;
(j)
Neither Parent nor any of its subsidiaries is (i) subject to regulation under the Investment Company Act of 1940 (as amended) or (ii) a “registered investment company” or a company “controlled” by a “registered investment company” or a “principal underwriter” of a “registered investment company” as such terms are defined in the Investment Company Act of 1940 (as amended);
(k)
None of Parent and its subsidiaries (the “Parent Group”), nor any of Parent’s or their respective joint ventures, directors, officers or employees nor, to Parent’s knowledge, any Persons acting on any of their behalf (a) is a Restricted Party; or (b) has received notice of or is aware of any claim, action, suit, proceeding or investigation against it with respect to Sanctions by any Sanctions Authority; and
(l)
The operations of each member of the Parent Group are and have been conducted at all times in compliance with all applicable Anti-Money Laundering Laws, Anti-Terrorism Laws and Anti-Corruption Laws and no action, suit or proceeding by or before any Governmental Authority or any arbitrator involving a member of the Group with respect to Anti-Money Laundering Laws, Anti-Terrorism Laws and/or Anti-Corruption Laws is pending and no such actions, suits or proceedings are threatened or contemplated.
2.
The Parent hereby covenants and agrees for the benefit of the Aval Provider that:
(a)
Parent shall maintain and preserve (i) its existence as a corporation in good standing in the state of its formation and its qualification to do business in each other jurisdiction where such qualification is necessary to perform its obligations hereunder and (ii) all material rights, privileges and franchises necessary in the normal course of conduct of its business, except any such rights, qualifications, privileges and franchises the failure

3


to maintain would not reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder or thereunder;
(b)
Parent shall comply with all requirements of applicable law, except where such non-compliance would not reasonably be expected to have a material adverse effect on the ability of the Parent to perform its obligations hereunder;
(c)
Parent shall not, and will not permit or authorize any other Person to, directly or indirectly, use, lend, make payments of, contribute or otherwise make available, all or any part of the proceeds of any Bank Guarantee or other transaction(s) contemplated by the Facility Documents to fund any trade, business or other activities: in any manner that would reasonably be expected to result in any member of the Parent Group or Aval Provider being in breach of Anti-Money Laundering Laws, Anti-Terrorism Laws and/or Anti-Corruption Laws (if and to the extent applicable to them);
(d)
Parent shall not at any time cease to own and control, (A) directly or indirectly, 100% of the securities having ordinary voting power for the election of directors (or persons performing similar functions) of TPO and NSF, excluding any incentive distribution rights in TPO (as in effect on the date hereof), and (B) directly, or indirectly through TPO and NSF, 100% of the voting power of the membership interests and economic interests of the Applicant, excluding any incentive distribution rights in TPO (as in effect on the date hereof);
(e)
Parent shall cause to be maintained the minimum amounts available to be drawn at all times under the Backstop Agreements as follows: (1) no less than US$400,000,000 under the Revolver and (2) no less than US$500,000,000 under the Sponsor Line. Parent shall provide evidence reasonably acceptable to the Aval Provider promptly upon written request that, that such minimum availability exists under the Backstop Agreements;
(f)
Parent shall not cause or permit the creation of, nor assume or suffer to exist, any lien on equity capital of NSF or the Applicant which secures a charge or obligation on any of such equity capital, real or personal, whether now owned or hereafter acquired, except as otherwise permitted pursuant to the Facility Documents;
(g)
Parent shall not cause, make, suffer, permit or consent to any creation, sale, assignment or transfer of any ownership interest or other interest in NSF, TPO or the Applicant, except as expressly contemplated by the Facility Documents or otherwise permitted by the Aval Provider;
(h)
Parent shall not cause, make, suffer, permit or consent to any modification of, or amendment, waiver or termination of, any of the Backstop Agreements or Irrevocable Agreements or any of the agreements or documents relating to the Santander Facility that is in any manner adverse to the Aval Provider; and
(i)
In the event that the Aval Provider shall demand that Applicant fund any Cash Collateral Deposit pursuant to Section 8.2 of the Bank Guarantee Agreement, Parent shall:

4


(i)
promptly (and in any event not more than (x) three (3) Business Days with respect to any drawing described in sub-clause (a) immediately below or (y) forty-five (45) days following the applicable demand with respect to any issuance described in sub-clause (b) immediately below) cause Parent to take (and/or cause its applicable subsidiaries, including TPO, as the case may be, to take) the following actions to the extent required to ensure that the Applicant has available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding amount drawn under the Bank Guaranty (together with any other Obligations then payable) and any corresponding collateralization, reimbursement or other obligations due under the Natixis Facility:
(a)
first, cause TPO to submit a request for and draw the maximum amount available to be drawn under the Revolver and/or submit a request for and draw the maximum amount available to be drawn under the Sponsor Line; and
(b)
second, issue and sell new shares of Class A common stock in Parent for net proceeds in an amount not to exceed US$400 million; and
(ii)
promptly (and in any event not more than forty-five (45) days following the disbursement of the proceeds from any such draw or issuance), cause Parent to make or cause to be made (and/or cause its applicable subsidiaries (including TPO), as the case may be, to make or cause to be made) equity contributions to Applicant (utilizing in whole or in part, in its sole discretion, an amount up to the net proceeds resulting from such drawings and/or issuance) to the extent required to ensure that the Applicant has immediately available cash in U.S. Dollars in an amount at least equal to any demanded cash collateral and (without duplication) outstanding amount drawn under the Bank Guaranty (together with any other Obligations then payable) and any corresponding and any corresponding collateralization, reimbursement or other obligations due under the Natixis Facility; provided that, notwithstanding the foregoing, in any event Applicant shall cause Parent to contribute or cause to be contributed (and/or cause its applicable subsidiaries (including TPO) (as the case may be) to contribute or cause to be contributed) the amounts required to be requested pursuant to Section 2.(i)(i)(a) above in an amount equal to the lesser of (x) US$900,000,000 and (y) the amount of any demanded cash collateral and (without duplication) outstanding amount drawn under the Bank Guaranty (together with any other Obligations then payable) to Applicant not more than eight (8) Business Days following the disbursement of the proceeds from any such draw or issuance.

5


3.
All rights of the Aval Provider and all obligations of the Parent hereunder shall be absolute and unconditional irrespective of: (i) any lack of validity, legality or enforceability of this Agreement, the other Facility Documents or the Backstop Agreements; (ii) the failure of Aval Provider (A) to assert any claim or demand or to enforce any right or remedy against the Applicant, the Parent or any other Person (including any guarantor) under the provisions of the Facility Documents, the Backstop Agreements or otherwise, or (B) to exercise any right or remedy against any other Credit Party; (iii) any change in the time, manner or place of payment of, or in any other term of, all or any portion of the obligations, or any other extension or renewal of any obligation of the Applicant, the Parent, the other Credit Parties, or otherwise; (iv) any reduction, limitation, impairment or termination of any of the obligations of the Applicant, Parent or the other Credit Parties for any reason other than the written agreement of the Aval Provider, and shall not be subject to, and the Parent hereby waives any right to or claim of, any defense or setoff, counterclaim, recoupment or termination whatsoever by reason of the invalidity, illegality, non-genuineness, irregularity, compromise or unenforceability of, or any other event or occurrence affecting, any obligation of the Applicant, the Parent, the other Credit Parties or otherwise; (v) any amendment to, waiver or other modification of, or any consent to departure from, any of the terms of this Agreement or the other Facility Documents; or (vi) any other circumstance which might otherwise constitute a defense available to, or a legal or equitable discharge of, Applicant, the Parent, the other Credit Parties (other than the defense of payment of the applicable amounts).
4.
The Aval Provider acknowledges and agrees that Parent’s obligations under this Agreement are as expressly set forth herein and that such obligations are not intended to, and do not, constitute a guarantee by Parent of Applicant’s Obligations under the Bank Guarantee Agreement.
5.
The Aval Provider may demand specific performance of this Agreement. The Parent hereby irrevocably waives, to the extent it may do so under applicable law, any defense based on the adequacy of a remedy at law that may be asserted as a bar to the remedy of specific performance in any action brought against the Parent for specific performance of this Agreement by the Aval Provider or any successor or assign thereof.
6.
This Agreement shall be governed and construed in accordance with the laws of the State of New York. For the purposes of any proceeding, action or suit involving this Agreement, each party hereto hereby expressly submits to the jurisdiction of any court of record of New York State or the United States located in the City of New York, Borough of Manhattan, and agrees that any order, process or other paper may be served upon either party within or without such court’s jurisdiction by mailing a copy thereof to the affected party at its address (that with respect to the Aval Provider, shall be the Aval Provider’s address shown on the first page of the Bank Guarantee Agreement, and with respect to Parent, shall be Parent’s address shown on the first page of this Agreement). Parent agrees that service of all process in any such proceeding in any such court may be made by registered or certified mail, return receipt requested, to such address and agrees that service as provided above is sufficient to confer personal jurisdiction over Parent in any such proceeding in any such court, and otherwise constitutes effective and binding service in every respect. Each party waives any claim that

6


such proceeding, action or suit has been brought in an inconvenient forum. EACH PARTY WAIVES TRIAL BY JURY.
7.
Neither this Agreement nor any provision hereunder may be amended, modified, supplemented or waived except in a writing signed by the Parent and the Aval Provider.
8.
This Agreement may be executed in two or more counterparts, each of which shall be deemed to be an original, but all of which together shall constitute one and the same instrument, and shall become effective when one or more counterparts have been signed by each of the parties and delivered to the other parties.
 
[The next page is the signature page]


7



IN WITNESS WHEREOF, the parties hereto have executed this Agreement as of the date above first written.
Very truly yours,
 
BANCO SANTANDER, S.A.

 
By
/s/ Daniel Machuca Reyes
 
Name:
Daniel Machuca reyes
 
Title:
Executive Director

By
/s/ Fernando Fernandez de la Alegria
 
Name:
Fernando Fernandez de la Alegria
 
Title:
Executive Director


CONFIRMED AND AGREED TO:

TerraForm Power, Inc.
 
By
/s/ Andrea Rocheleau
 
Name:
Andrea Rocheleau
 
Title:
General Counsel and Secretary



[Signature Page to Letter Agreement]
Exhibit

Exhibit 21.1
List of Subsidiaries of TerraForm Power, Inc.

Name of Entity
Jurisdiction of Organization
TerraForm Power, LLC
Delaware
TerraForm Power Operating, LLC
Delaware
SunEdison Canada Yieldco Master Holdco, LLC
Delaware
SunEdison Canada Yieldco, LLC
Delaware
SunEdison Canada YieldCo Lindsay, LLC
Delaware
SunEdison Marsh Hill, LLC
Delaware
TerraForm Ontario Solar, LLC
Delaware
TerraForm Canada UTL Solar Holdings, Inc.
British Columbia
TerraForm Canada UTL Intermediate GP Inc.
British Columbia
TerraForm Canada UTL Solar Intermediate Holdings LP
Ontario
TerraForm Canada UTL GP Inc.
British Columbia
TerraForm Canada UTL Solar Holdings LP
Ontario
Lindsay Solar GP Inc.
British Columbia
Lindsay Solar LP
Ontario
Marsh Hill III GP, Inc. (f/k/a 2413465 Ontario, Inc.)
British Columbia
Marsh Hill III LP
Ontario
TerraForm Ontario Solar Holdings GP Inc.
British Columbia
TerraForm Ontario Solar LP
Ontario
SunEdison Yieldco Chile Master Holdco, LLC
Delaware
SunEdison Yieldco Chile HoldCo, LLC
Delaware
Amanecer Solar Holding SpA
Republic of Chile
Amanecer Solar Management SpA
Republic of Chile
Amanecer Solar SpA
Republic of Chile
SunEdison Yieldco ACQ1 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ1, LLC
Delaware
SunEdison Yieldco DG–VIII Master Holdco, LLC
Delaware
SunEdison Yieldco DG–VIII Holdings, LLC
Delaware
SunEdison PR DG, LLC
Delaware
SunE Solar VIII, LLC
Delaware
SunE WF CRS, LLC
Delaware
SunE Irvine Holdings, LLC
Delaware
SunE HB Holdings, LLC
Delaware
SunEdison Origination2, LLC
Delaware
SunE Solar VIII 2, LLC
Delaware
SunE GIL1, LLC
Delaware
SunE GIL2, LLC
Delaware
SunE GIL3, LLC
Delaware
SunE Gresham WWTP, LLC
Delaware
SunE WF Bellingham, LLC
Delaware
SunE WF Framingham, LLC
Delaware

1




SunE KHL PSNJ, LLC
Delaware
SunE WF Dedham, LLC
Delaware
SunE DDR PSNJ, LLC
Delaware
SunE W-PR1, LLC
Puerto Rico
SunE WMT PR3, LLC
Puerto Rico
SunE Irvine, LLC
Delaware
SunE HB, LLC
Delaware
SunE OC PSNJ, LLC
Delaware
SunE GIL Holdings, LLC
Delaware
SunE KHL968 Orange, LLC
Delaware
SunE WF10217 West Hartford, LLC
Delaware
SunE KHL1004 Hillsboro, LLC
Delaware
SunEdison Yieldco UK HoldCo 3 Master Holdco, LLC
Delaware
SunEdison Yieldco UK HoldCo 3, LLC
Delaware
Norrington Solar Farm Limited
United Kingdom
SunEdison Yieldco UK HoldCo 4 Master Holdco, LLC
Delaware
SunEdison Yieldco UK HoldCo 4, LLC
Delaware
SunEdison Yieldco UK HoldCo 2 Master Holdco, LLC
Delaware
SunEdison Yieldco UK HoldCo 2, LLC
Delaware
SunEdison Yieldco DG Master Holdco, LLC
Delaware
SunEdison Yieldco DG Holdings, LLC
Delaware
SunE Solar Construction Holdings #2, LLC
Delaware
SunE Solar Construction #2, LLC
Delaware
BWC Origination 2, LLC
Delaware
SunE CREST 1, LLC
Delaware
SunE CREST 2, LLC
Delaware
SunE CREST 5, LLC
Delaware
SunE CREST 6, LLC
Delaware
SunE CREST 7, LLC
Delaware
SunE CRF8, LLC
Delaware
SunE CRF9, LLC
Delaware
SunE CRF10, LLC
Delaware
SunE CRF12, LLC
Delaware
SunE LPT1, LLC
Delaware
SunE RBPC1, LLC
Delaware
SunE RBPC3, LLC
Delaware
SunE RBPC4, LLC
Delaware
SunE RBPC6, LLC
Delaware
SunE RBPC7, LLC
Delaware
SunE Solar Berlin I, LLC
Delaware
SunE Solar XV Holdco, LLC
Delaware
SunE Solar XV Lessor Parent, LLC
Delaware
SunE Solar XV Lessor, LLC
Delaware
SunEdison Yieldco Origination Holdings, LLC
Delaware

2




Belchertown Solar, LLC
Delaware
BWC Origination 12, LLC
Delaware
SunE Hubbardston Solar, LLC
Delaware
SunE Solar Mattapoisett I, LLC
Delaware
SunEdison DG14 Holdings, LLC
Delaware
SunEdison JJ Gurabo, LLC
Puerto Rico
Tioga Solar La Paz, LLC
Delaware
Treasure Valley Solar, LLC
Delaware
SunEdison Yieldco Nellis Master Holdco, LLC
Delaware
SunEdison Yieldco Nellis HoldCo, LLC
Delaware
NAFB LP Holdings, LLC
Delaware
MMA NAFB Power, LLC
Delaware
Solar Star NAFB, LLC
Delaware
SunEdison Yieldco Regulus Master Holdco, LLC
Delaware
SunEdison Yieldco Regulus Holdings, LLC
Delaware
SunE Regulus Managing Member, LLC
Delaware
SunE Regulus Equity Holdings, LLC
Delaware
SunE Regulus Holdings, LLC
Delaware
Regulus Solar, LLC
Delaware
SunEdison Yieldco ACQ2 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ2, LLC
Delaware
CalRENEW-1, LLC
Delaware
SunEdison Yieldco ACQ3 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ3, LLC
Delaware
SunE Alamosa1 Holdings, LLC
Delaware
SunE Alamosa1, LLC
Delaware
OL’s SunE Alamosa1 Trust
Delaware
SunEdison Yieldco ACQ9 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ9, LLC
Delaware
Atwell Island Holdings, LLC
Delaware
SPS Atwell Island, LLC
Delaware
SunEdison Yieldco ACQ4 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ4, LLC
Delaware
Yieldco SunEY US Holdco, LLC
Delaware
Green Cove Management, LLC
Florida
SunEY Solar Dev Co, LLC
Delaware
SunEY Solar Funding II, LLC
Delaware
SunEY Solar Funding IV, LLC
Delaware
SS San Antonio West, LLC
California
SunEY Solar Gibbstown, LLC
Delaware
SunEY Solar I, LLC
Delaware
SunEY Solar Liberty, LLC
Delaware
SunEY Solar Ocean City One, LLC
Delaware
SunEY Solar St. Joseph’s LLC
Delaware
SunEY Solar Lindenwold BOE, LLC
Delaware

3




SunEY Solar Ocean City Two, LLC
Delaware
SunEY Solar Power I, LLC
Delaware
SunEY Sequoia I, LLC
Delaware
SunEY Solar Power II, LLC
Delaware
SunEY Solar Frederick BOE, LLC
Delaware
SunEY Solar Hazlet BOE, LLC
Delaware
SunEY Solar Medford BOE, LLC
Delaware
SunEY Solar Medford Lakes, LLC
Delaware
SunEY Solar Talbot County, LLC
Delaware
SunEY Solar Wayne BOE, LLC
Delaware
SunEY Solar Power III, LLC
Delaware
Solar PPA Partnership One, LLC
New York
SunEY Solar Cresskill BOE, LLC
Delaware
SunEY Solar KMBS, LLC
Delaware
Waldo Solar Energy Park of Gainesville, LLC
Delaware
SunEY Solar Silvermine, LLC
Delaware
SunEY Solar Solomon Schechter, LLC
Delaware
SunEY Solar SWBOE, LLC
Delaware
SunEY Solar WPU, LLC
Delaware
SunEdison Yieldco ACQ5 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ5, LLC
Delaware
SunEdison Yieldco Enfinity Master Holdco, LLC
Delaware
SunEdison Yieldco, Enfinity Holdings, LLC
Delaware
Enfinity SPV Holdings 2, LLC
Delaware
Enfinity Holdings WF LLC
Delaware
Enfinity NorCal 1 FAA, LLC
California
Enfinity Arizona 2 Camp Verde USD LLC
Arizona
Enfinity Arizona 3 Winslow USD LLC
Arizona
Enfinity BNB Napoleon Solar, LLC
Delaware
Enfinity CentralVal 5 LUESD LLC
California
SunEdison Yieldco DGS Master Holdco, LLC
Delaware
SunEdison Yieldco, DGS Holdings, LLC
Delaware
SunE DGS Master Tenant, LLC
Delaware
SunE DGS Owner Holdco, LLC
Delaware
SunE Corcoran SP Owner, LLC
Delaware
SunE Solano SP Owner, LLC
Delaware
SunE Wasco SP Owner, LLC
Delaware
SunE Coalinga SH Owner, LLC
Delaware
SunE Pleasant Valley SP Owner, LLC
Delaware
SunEdison Yieldco ACQ7 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ7, LLC
Delaware
MA Operating Holdings, LLC
Delaware
Fall River Commerce Solar Holdings, LLC
Delaware
Fall River Innovation Solar Holdings, LLC
Delaware
South Street Solar Holdings, LLC
Delaware

4




Uxbridge Solar Holdings, LLC
Delaware
SunEdison Yieldco ACQ8 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ8, LLC
Delaware
SunEdison DG Operating Holdings-2, LLC
Delaware
SunEdison Yieldco ACQ6 Master Holdco, LLC
Delaware
SunEdison Yieldco ACQ6, LLC
Delaware
TerraForm Power Solar X Holdings, LLC
Delaware
SunE Solar X, LLC
Delaware
SunE J10 Holdings, LLC
Delaware
SE Solar Trust X, LLC
Delaware
TerraForm Power IVS I Master Holdco, LLC
Delaware
TerraForm Power IVS I Holdings, LLC
Delaware
TerraForm Power IVS I Holdings II, LLC
Delaware
IVS I Services, LLC
Delaware
Imperial Valley Solar 1 Holdings II, LLC
Delaware
Imperial Valley Solar 1 Holdings, LLC
Delaware
Imperial Valley Solar 1 Intermediate Holdings, LLC
Delaware
Imperial Valley Solar 1, LLC
Delaware
TerraForm LPT ACQ Master Holdco, LLC
Delaware
TerraForm LPT ACQ Holdings, LLC
Delaware
TerraForm 2014 LPT II ACQ Holdings, LLC
Delaware
SunE Solar XVI Manager, LLC
Delaware
SunE Solar XVI Holdings, LLC
Delaware
SunE Solar XVI Lessor, LLC
Delaware
TerraForm Solar Master Holdco, LLC
Delaware
TerraForm Solar Holdings, LLC
Delaware
TerraForm Hudson Energy Solar, LLC
Delaware
Hudson USB ITC Managing Member, LLC
Delaware
Hudson USB ITC Managing Member 2, LLC
Delaware
Hudson Solar Macy, LLC
Delaware
Hudson USB ITC Tenant LLC
Delaware
Hudson USB ITC Owner LLC
Delaware
Hudson USB ITC Tenant 2 LLC
Delaware
Hudson USB ITC Owner 2 LLC
Delaware
Hudson Solar Project 1 LLC
Delaware
Hudson Solar Project 2, LLC
Delaware
Hudson Solar Project 3 LLC
Delaware
SunEdison Yieldco DG Master Holdco, LLC
Delaware
SunEdison YieldCo DG Holdings, LLC
Delaware
SunEdison YieldCo Origination Holdings, LLC
Delaware
SunEdison NC Utility, LLC
Delaware
SunEdison NC Utility 2, LLC
Delaware
SunE Dessie Managing Member, LLC
Delaware
SunE Dessie Equity Holdings, LLC
Delaware
Dessie Solar Center, LLC
North Carolina

5




Bearpond Solar Center, LLC
North Carolina
SunE NC Lessee Managing Member, LLC
Delaware
SunE NC Lessee Holdings, LLC
Delaware
SunE Bearpond Lessee, LLC
Delaware
SunE Shankle Lessee, LLC
Delaware
SunE Graham Lessee, LLC
Delaware
SunE Bearpond Lessor Managing Member, LLC
Delaware
SunE Graham Lessor Managing Member, LLC
Delaware
SunE Shankle Lessor Managing Member, LLC
Delaware
SunE Bearpond Lessor Holdings, LLC
Delaware
SunE Graham Lessor Holdings, LLC
Delaware
Graham Lessor Holdings Corporation
Delaware
SunE Shankle Lessor Holdings, LLC
Delaware
Shankle Lessor Holdings Corporation
Delaware
Shankle Solar Center, LLC
North Carolina
Graham Solar Center, LLC
North Carolina
TerraForm CD ACQ Master Holdco, LLC
Delaware
TerraForm CD ACQ Holdings, LLC
Delaware
TerraForm CD Intermediate Holdings, LLC
Delaware
TerraForm CD Holdings Corporation
Delaware
TerraForm CD Holdings GP, LLC
Delaware
TerraForm CD Holdings, LLC
Delaware
Capital Dynamics US Solar Holdings 1, Inc.
Delaware
Capital Dynamics US Solar AIV - A, L.P.
Delaware
Capital Dynamics US Solar-PA 1, LLC
Delaware
BASD Buchanan Solar LLC
Delaware
BASD East Hills Solar LLC
Delaware
BASD Farmersville Solar LLC
Delaware
BASD Freedom Solar I LLC
Delaware
BASD Solar, LLC
Delaware
BASD Spring Garden Solar LLC
Delaware
CIT Solar, LLC
Delaware
Colonial Solar, LLC
Delaware
Laureldale Solar, LLC
Delaware
Capital Dynamics US Solar Holdings 3, Inc.
Delaware
Capital Dynamics US Solar AIV - C, L.P.
Delaware
Capital Dynamics US Solar CA-2, LLC
Delaware
Cami Solar, LLC
Nevada
Capital Dynamics US Solar Holdings 2, Inc.
Delaware
Capital Dynamics US Solar AIV - B, L.P.
Delaware
CD US Solar Marketing 2, LLC
Delaware
CD US Solar MT 2, LLC
Delaware
CD US Solar PO 2, LLC
Delaware
Capital Dynamics US Solar Holdings 4, Inc.
Delaware
Capital Dynamics US Solar AIV - D, L.P.
Delaware

6




CD US Solar Marketing, LLC
Delaware
CD US Solar MT 1, LLC
Delaware
CD US Solar PO 1, LLC
Delaware
Capital Dynamics US Solar AIV - G, L.P.
Delaware
CD US Solar Sponsor, LLC
Delaware
CD US Solar Developer, LLC
Delaware
Capital Dynamics US Solar Holdings 5, Inc.
Delaware
Capital Dynamics US Solar AIV - E, L.P.
Delaware
CD US Solar MT 3, LLC
Delaware
CD US Solar PO 3, LLC
Delaware
TerraForm REC ACQ Master Holdco, LLC
Delaware
TerraForm REC ACQ Holdings, LLC
Delaware
TerraForm REC Holdings, LLC
Delaware
TerraForm REC Operating, LLC
Delaware
TerraForm Solar XVII ACQ Master Holdco, LLC
Delaware
TerraForm Solar XVII ACQ Holdings, LLC
Delaware
TerraForm Solar XVII Manager, LLC
Delaware
TerraForm Solar XVII, LLC
Delaware
SunE 29 Palms, LLC
Delaware
SunE CasimirES, LLC
Delaware
SunE DB10, LLC
Delaware
SunE DB11, LLC
Delaware
SunE DB12, LLC
Delaware
SunE DB15, LLC
Delaware
SunE DB17, LLC
Delaware
SunE DB18, LLC
Delaware
SunE DB20, LLC
Delaware
SunE DB24, LLC
Delaware
SunE DB33, LLC
Delaware
SunE DB34, LLC
Delaware
SunE DB36, LLC
Delaware
SunE DG3, LLC
Delaware
SunE DG6, LLC
Delaware
SunE DG12, LLC
Delaware
SunE DG13, LLC
Delaware
SunE DG14, LLC
Delaware
SunE DG15, LLC
Delaware
SunE DG16, LLC
Delaware
SunE DG17, LLC
Delaware
SunE DG18, LLC
Delaware
SunE EshlemanHall, LLC
Delaware
SunE SEM 2, LLC
Delaware
SunE SEM 3, LLC
Delaware
BWC Origination 10, LLC
Delaware
SunE Solar XVII Project1, LLC
Delaware

7




SunE Solar XVII Project2, LLC
Delaware
SunE Solar XVII Project3, LLC
Delaware
TerraForm First Wind ACQ Master Holdco, LLC
Delaware
TerraForm First Wind ACQ, LLC
Delaware
First Wind Operating Company, LLC
Delaware
Hawaiian Island Holdings, LLC
Delaware
First Wind Kahuku Holdings, LLC
Delaware
Kahuku Holdings, LLC
Delaware
Kahuku Wind Power, LLC
Delaware
Hawaii Holdings, LLC
Delaware
Kaheawa Wind Power II, LLC
Delaware
First Wind HWP Holdings, LLC
Delaware
Hawaii Wind Partners, LLC
Delaware
Hawaii Wind Partners II, LLC
Delaware
Kaheawa Wind Power, LLC
Delaware
First Wind Northeast Company, LLC
Delaware
Northeast Wind Partners II, LLC
Delaware
Northeast Wind Capital Holdings, LLC
Delaware
Northeast Wind Capital II, LLC
Delaware
Maine Wind Partners II, LLC
Delaware
Maine Wind Partners, LLC
Delaware
Evergreen Wind Power, LLC
Delaware
Rollins Holdings, LLC
Delaware
Evergreen Wind Power III, LLC
Delaware
Stetson Wind Holdings Company, LLC
Delaware
Stetson Holdings, LLC
Delaware
Stetson Wind II, LLC
Delaware
Evergreen Gen Lead, LLC
Delaware
First Wind Blue Sky East Holdings, LLC
Delaware
Blue Sky East Holdings, LLC
Delaware
Blue Sky East, LLC
Delaware
Sheffield Wind Holdings, LLC
Delaware
Sheffield Holdings, LLC
Delaware
Vermont Wind, LLC
Delaware
CSSW Cohocton Holdings, LLC
Delaware
New York Wind, LLC
Delaware
Canandaigua Power Partners, LLC
Delaware
Canandaigua Power Partners II, LLC
Delaware
CSSW Steel Winds Holdings, LLC
Delaware
Huron Holdings, LLC
Delaware
Erie Wind, LLC
Delaware
Niagara Wind Power, LLC
Delaware
FW Mass PV Portfolio, LLC
Delaware
FWPV Capital, LLC
Delaware
FWPV Holdings, LLC
Delaware
FWPV, LLC
Delaware

8




Mass Solar 1 Holdings, LLC
Delaware
Mass Solar 1, LLC
Delaware
Mass Midstate Solar 1, LLC
Delaware
Mass Midstate Solar 2, LLC
Delaware
Mass Midstate Solar 3, LLC
Delaware
Millbury Solar, LLC
Delaware
TerraForm Thor ACQ Master Holdco, LLC
Delaware
TerraForm Thor ACQ Holdings, LLC
Delaware
TerraForm Private Holdings II, LLC
Delaware
TerraForm Private II, LLC
Delaware
TerraForm Private Operating II, LLC
Delaware
FW Panhandle Portfolio II, LLC
Delaware
First Wind Panhandle Holdings II, LLC
Delaware
First Wind South Plains Portfolio, LLC
Delaware
First Wind Texas Holdings II, LLC
Delaware
South Plains Wind Energy, LLC
Delaware
TerraForm IWG Acquisition Holdings, LLC
Delaware
Rattlesnake Wind I Class B Holdings LLC
Delaware
Rattlesnake Wind I Holdings LLC
Delaware
Rattlesnake Wind I LLC
Delaware
TerraForm IWG Acquisition Ultimate Holdings II, LLC
Delaware
TerraForm IWG Acquisition Intermediate Holdings II, LLC
Delaware
TerraForm IWG Acquisition Holdings II Parent, LLC
Delaware
TerraForm IWG Acquisition Holdings II, LLC
Delaware
Bishop Hill Class B Holdings LLC
Delaware
Bishop Hill Holdings LLC
Delaware
Bishop Hill Energy LLC
Delaware
TerraForm IWG Acquisition Holdings III, LLC
Delaware
California Ridge Class B Holdings LLC
Delaware
California Ridge Holdings LLC
Delaware
California Ridge Wind Energy LLC
Delaware
Invenergy Prairie Breeze Holdings LLC
Delaware
Prairie Breeze Class B Holdings LLC
Delaware
Prairie Breeze Holdings LLC
Delaware
Prairie Breeze Wind Energy LLC
Delaware
TerraForm IWG Ontario Holdings Grandparent, LLC
Delaware
TerraForm IWG Ontario Holdings Parent, LLC
Delaware
TerraForm IWG Ontario Holdings, LLC
Delaware
TerraForm Utility Solar XIX Holdings, LLC
Delaware
TerraForm Utility Solar XIX Manager, LLC
Delaware
TerraForm Utility Solar XIX, LLC
Delaware
Beryl Solar, LLC
Delaware
Buckhorn Solar, LLC
Delaware
Cedar Valley Solar, LLC
Delaware
Granite Peak Solar, LLC
Delaware
Greenville Solar, LLC
Delaware

9




Laho Solar, LLC
Delaware
LKL BLBD, LLC
Delaware
Milford Flat Solar, LLC
Delaware
River Mountains Solar, LLC
Delaware
SunE DB APNL, LLC
Delaware
SunEdison Yieldco ACQ10, LLC
Delaware
TerraForm Dairyland Acquisitions, LLC
Delaware
Integrys Solar, LLC
Delaware
Gilbert Solar Facility I, LLC
Delaware
INDU Solar Holdings, LLC
Delaware
Berkley East Solar LLC
Delaware
ISH Solar AZ, LLC
Delaware
ISH Solar Beach, LLC
Delaware
ISH Solar CA, LLC
Delaware
ISH Solar Central, LLC
Delaware
ISH Solar Hospitals, LLC
Delaware
ISH Solar Mouth, LLC
Delaware
SEC BESD Solar One, LLC
Delaware
SEC Bellefonte SD Solar One, LLC
Delaware
Sterling Solar LLC
Delaware
Solar Hold 2008 – 1, LLC
Delaware
Integrys NJ Solar, LLC
Delaware
Solar Star California II, LLC
Delaware
Soltage – ADC 630 Jamesburg, LLC
Delaware
Soltage – MAZ 700 Tinton Falls, LLC
Delaware
Soltage – PLG 500 Milford, LLC
Delaware
Solar Star New Jersey VI, LLC
Delaware
TerraForm Energy Services Holdings, LLC
Delaware
TerraForm US Energy Services, LLC
Delaware
TerraForm Canada Energy Services, Inc.
British Columbia
TerraForm Italy LDV Holdings, LLC
Delaware
TerraForm Japan Holdco, LLC
Delaware
TerraForm Japan Holdco GK
Japan
TerraForm Power Holdings B.V.
Netherlands
TerraForm Power Finance B.V.
Netherlands
TerraForm PR Holdings 1, LLC
Delaware
TerraForm Solar IX Holdings, LLC
Delaware
SunE B9 Holdings, LLC
Delaware
TerraForm Solar XVIII ACQ Holdings, LLC
Delaware
TerraForm Solar XVIII Manager, LLC
Delaware
TerraForm Solar XVIII, LLC
Delaware
SunE DB3, LLC
Delaware
SunE DB8, LLC
Delaware
SunE DB27, LLC
Delaware
SunE DB42, LLC
Delaware
SunE DB43, LLC
Delaware

10




SunE DB44, LLC
Delaware
SunE DB45, LLC
Delaware
SunE DG1, LLC
Delaware
SunE DG2, LLC
Delaware
SunE DG8, LLC
Delaware
SunE DG25, LLC
Delaware
SunE IM Pflugerville, LLC
Delaware
SunE HARD Mission Hills, LLC
Delaware
SunE HH Blue Mountain, LLC
Delaware
SunE HH Buchanan, LLC
Delaware
SunE HH Frank Lindsey, LLC
Delaware
SunE HH Furnace Woods, LLC
Delaware
SunE HH Hudson High, LLC
Delaware
Oak Leaf Solar V LLC
Delaware
Water Street Solar 1, LLC
Delaware
TerraForm MP Holdings, LLC
Delaware
TerraForm MP Solar, LLC
Delaware
TerraForm Ontario Solar Holdings, LLC
Delaware
TerraForm KWP Investor Holdings, LLC
Delaware
KWP Upwind Holdings LLC
Delaware



11


Exhibit
Exhibit 23.1

Consent of Independent Registered Public Accounting Firm
The Board of Directors
TerraForm Power, Inc.:
We consent to the incorporation by reference in the registration statements (No. 333‑205337) on Form S-8 and (No. 333-221593) on Form S-1 of TerraForm Power, Inc. of our reports dated March 7, 2018, with respect to the consolidated balance sheets of TerraForm Power, Inc. and subsidiaries as of December 31, 2017 and 2016, and the related consolidated statements of operations, comprehensive loss, stockholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2017, and the related notes (collectively, the consolidated financial statements), and the effectiveness of internal control over financial reporting as of December 31, 2017, which reports appear in the December 31, 2017 annual report on Form 10‑K of TerraForm Power, Inc.
Our report dated March 7, 2018, on the effectiveness of internal control over financial reporting as of December 31, 2017, expresses our opinion that TerraForm Power, Inc. and subsidiaries (the Company) did not maintain effective internal control over financial reporting as of December 31, 2017 because of the effect of material weaknesses on the achievement of the objectives of the control criteria and contains an explanatory paragraph that states the following material weaknesses have been identified:
The Company did not have sufficient resources, including contractors, in place throughout the reporting period with the appropriate training and knowledge of internal controls over financial reporting in order to establish the Company’s financial reporting processes and information technology (IT) systems and to design, implement and operate an effective system of internal control over financial reporting.
The Company did not conduct continuous risk assessment and monitoring activities over financial reporting and IT systems to identify and analyze risks of financial misstatement due to error and/or fraud and to identify and assess necessary changes in generally accepted accounting principles (GAAP) and financial reporting processes and internal controls impacted by changes in the business, information systems, and transition of key personnel.
The Company did not have an effective information and communication process that ensured appropriate and accurate information was available to financial reporting personnel on a timely basis in order that they could fulfill their roles and responsibilities.
The Company did not have effective IT general controls over all operating systems, databases, and IT applications supporting financial reporting. Process-level automated controls and manual controls that were dependent upon the information derived from IT systems were also determined to be ineffective. Additionally, the Company did not have effective end-user computing controls over spreadsheets used in financial reporting.
The Company did not have effective controls over the completeness, existence, and accuracy of revenues and deferred revenue and the completeness, existence, accuracy and valuation of accounts receivable.
The Company did not have effective reconciliation controls over the completeness, existence and accuracy of certain balance sheet accounts. Specifically, the reconciliation controls did not always operate timely and did not adequately investigate, resolve and correct reconciling items on a timely basis.
The Company did not have effective controls over the completeness, existence and accuracy of accounts payable, accrued expenses, and expenses. Specifically, the Company did not establish an effective accounts payable voucher and disbursement process and related internal controls in order to review and approve and accurately record expenditures on a timely basis.
The Company did not have effective controls over the completeness, existence and accuracy of renewable energy facilities, accumulated depreciation and depreciation, accretion and amortization expense.
The Company did not have effective process level and management review controls over the application of GAAP and accounting measurements related to certain significant accounts and non-routine transactions.
The Company did not have effective process-level and management review controls over manual financial reporting processes. Specifically, the Company did not have effective controls over the completeness and accuracy of information used in manual spreadsheets and the accuracy of those spreadsheet formulas.
/s/ KPMG LLP
McLean, Virginia
March 7, 2018

Exhibit


Exhibit 31.1

Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002


I, John Stinebaugh, Chief Executive Officer, certify that:

1
I have reviewed this annual report on Form 10-K of TerraForm Power, Inc.;
2
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4
The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
 
a)
designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision; to ensure that material information relating to the registrant, including its consolidated subsidiaries is made known to us by others within those entities, particularly during the period in which this report is being prepared;
 
b)
designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
 
c)
evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
 
d)
disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.
5
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent function):
 
a)
all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
 
b)
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


Date:
March 7, 2018
 
 
 
By:
/s/ JOHN STINEBAUGH
Name:
John Stinebaugh
Title:
Chief Executive Officer
 
(Principal executive officer)


Exhibit


Exhibit 31.2

Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002


I, Matthew Berger, Chief Financial Officer, certify that:

1
I have reviewed this annual report on Form 10-K of TerraForm Power, Inc.;
2
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4
The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
 
a)
designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision; to ensure that material information relating to the registrant, including its consolidated subsidiaries is made known to us by others within those entities, particularly during the period in which this report is being prepared;
 
b)
designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
 
c)
evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
 
d)
disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.
5
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent function):
 
a)
all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
 
b)
any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


Date:
March 7, 2018
 
 
 
By:
/s/ MATTHEW BERGER
Name:
Matthew Berger
Title:
Chief Financial Officer
 
(Principal financial officer and principal accounting officer)


Exhibit


Exhibit 32
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the annual report of TerraForm Power, Inc. (the “Company”) on Form 10-K for the period ending December 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), we, John Stinebaugh, Chief Executive Officer of the Company, and Matthew Berger, Chief Financial Officer of the Company, certify, to the best of our knowledge, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:
 
1
The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
 
2
The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:
March 7, 2018
 
 
 
By:
/s/ JOHN STINEBAUGH
Name:
John Stinebaugh
Title:
Chief Executive Officer
 
(Principal executive officer)

Date:
March 7, 2018
 
 
 
By:
/s/ MATTHEW BERGER
Name:
Matthew Berger
Title:
Chief Financial Officer
 
(Principal financial officer and principal accounting officer)