10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2020

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

Commission File Number: 001-36002

Clearway Energy, Inc.

(Exact name of registrant as specified in its charter)

Delaware			46-1777204
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)
300 Carnegie Center, Suite 300	Princeton	New Jersey	08540
(Address of principal executive offices)			(Zip Code)

(609) 608-1525

(Registrant’s telephone number, including area code)

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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Class A Common Stock, par value $0.01	CWEN.A	New York Stock Exchange
Class C Common Stock, par value $0.01	CWEN	New York Stock Exchange

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 ☒       No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).

Yes ☒      No ☐

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	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

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

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

Yes ☐       No ☒

As of July 31, 2020, there were 34,599,645 shares of Class A common stock outstanding, par value $0.01 per share, 42,738,750 shares of Class B common stock outstanding, par value $0.01 per share, 80,602,613 shares of Class C common stock outstanding, par value $0.01 per share, and 42,738,750 shares of Class D common stock outstanding, par value $0.01 per share.

TABLE OF CONTENTS

Index

CAUTIONARY STATEMENT REGARDING FORWARD LOOKING INFORMATION	3
GLOSSARY OF TERMS	4
PART I — FINANCIAL INFORMATION	7
ITEM 1 — FINANCIAL STATEMENTS AND NOTES	7
ITEM 2 — MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	41
ITEM 3 — QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	62
ITEM 4 — CONTROLS AND PROCEDURES	63
PART II — OTHER INFORMATION	64
ITEM 1 — LEGAL PROCEEDINGS	64
ITEM 1A — RISK FACTORS	64
ITEM 2 — UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	64
ITEM 3 — DEFAULTS UPON SENIOR SECURITIES	64
ITEM 4 — MINE SAFETY DISCLOSURES	64
ITEM 5 — OTHER INFORMATION	64
ITEM 6 — EXHIBITS	65
SIGNATURES	66

2

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q of Clearway Energy, Inc., together with its consolidated subsidiaries, or the Company, includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, or the Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended, or the Exchange Act. The words "believes," "projects," "anticipates," "plans," "expects," "intends," "estimates" and similar expressions are intended to identify forward-looking statements. These forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause the Company's actual results, performance and achievements, or industry results, to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. These factors, risks and uncertainties include the factors described under Item 1A — Risk Factors in Part II of this Quarterly Report on Form 10-Q, under Item 1A — Risk Factors in Part II of the Company's Quarterly Report on Form 10-Q for the fiscal quarter ended March 31, 2020 and under Item 1A — Risk Factors in Part I of the Company's Annual Report on Form 10-K for the year ended December 31, 2019, as well as the following:

•Potential risks related to the PG&E Bankruptcy;

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

•Potential risks related to the Company's relationships with GIP and CEG, including the Company's ability to acquire assets from GIP or CEG;

•Potential risks related to COVID-19 or any other pandemic;

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

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

•Changes in law, including judicial decisions;

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

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

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

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

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

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

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

•The Company's ability to engage in successful mergers and acquisitions activity; and

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

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

3

GLOSSARY OF TERMS

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

2019 Form 10-K	Clearway Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2019
2020 Convertible Notes	$45 million aggregate principal amount of 3.25% convertible notes due 2020, issued by Clearway Energy, Inc., which were repaid on June 1, 2020
2024 Senior Notes	$500 million aggregate principal amount of 5.375% unsecured senior notes due 2024, issued by Clearway Energy Operating LLC
2025 Senior Notes	$600 million aggregate principal amount of 5.750% unsecured senior notes due 2025, issued by Clearway Energy Operating LLC
2026 Senior Notes	$350 million aggregate principal amount of 5.00% unsecured senior notes due 2026, issued by Clearway Energy Operating LLC
2028 Senior Notes	$850 million aggregate principal amount of 4.750% unsecured senior notes due 2028, issued by Clearway Energy Operating LLC
Adjusted EBITDA	A non-GAAP measure, represents earnings before interest, tax, depreciation and amortization adjusted for mark-to-market gains or losses, asset write offs and impairments; and factors which the Company does not consider indicative of future operating performance
AOCI	Accumulated Other Comprehensive Income
ASC	The FASB Accounting Standards Codification, which the FASB established as the source of authoritative GAAP
ASU	Accounting Standards Updates - updates to the ASC
ATM Program	At-The-Market Equity Offering Program
Bankruptcy Code	Title 11 of the U.S. Code
Bankruptcy Court	U.S. Bankruptcy Court for the Northern District of California
CAFD	A non-GAAP measure, Cash Available for Distribution is defined as of June 30, 2020 as Adjusted EBITDA plus cash distributions/return of investment from unconsolidated affiliates, adjustments to reflect CAFD generated by unconsolidated investments that were not able to distribute project dividends due to the PG&E Bankruptcy as of June 30, 2020, cash receipts from notes receivable, cash distributions from noncontrolling interests, less cash distributions to noncontrolling interests, maintenance capital expenditures, pro-rata Adjusted EBITDA from unconsolidated affiliates, cash interest paid, income taxes paid, principal amortization of indebtedness, Walnut Creek investment payments, and changes in prepaid and accrued capacity payments, and adjusted for development expenses
CEG	Clearway Energy Group LLC (formerly Zephyr Renewables LLC)
CEG Master Services Agreements	Master Services Agreements entered into as of August 31, 2018 between the Company, Clearway Energy LLC and Clearway Energy Operating LLC, and CEG
Clearway Energy LLC	The holding company through which the projects are owned by Clearway Energy Group LLC, the holder of Class B and Class D units of the Company, and Clearway Energy, Inc., the holder of the Class A and Class C units
Clearway Energy Group LLC	The holder of the Company's Class B and Class D common shares and Clearway Energy LLC's Class B and Class D units
Clearway Energy Operating LLC	The holder of the project assets that are owned by Clearway Energy LLC
COD	Commercial Operation Date
Company	Clearway Energy, Inc. together with its consolidated subsidiaries
CVSR	California Valley Solar Ranch
CVSR Holdco	CVSR Holdco LLC, the indirect owner of CVSR
DGPV Holdco 1	DGPV Holdco 1 LLC
DGPV Holdco 2	DGPV Holdco 2 LLC
DGPV Holdco 3	DGPV Holdco 3 LLC

4

Distributed Solar	Solar power projects, typically less than 20 MW in size, that primarily sell power produced to customers for usage on site, or are interconnected to sell power into the local distribution grid
Drop Down Assets	Collectively, assets under common control acquired by the Company from NRG from January 1, 2014 through the period ended August 31, 2018 and from CEG from August 31, 2018 through the period ending June 30, 2020
Economic Gross Margin	A non-GAAP measure, energy and capacity revenue less cost of fuels
ECP	Energy Center Pittsburgh LLC, a subsidiary of the Company
EPA	U.S. Environmental Protection Agency
Exchange Act	The Securities Exchange Act of 1934, as amended
FASB	Financial Accounting Standards Board
GAAP	Accounting principles generally accepted in the U.S.
GenConn	GenConn Energy LLC
GIP	Collectively, Global Infrastructure Partners III-C Intermediate AIV 3, L.P., Global Infrastructure Partners III-A/B AIV 3, L.P., Global Infrastructure Partners III-C Intermediate AIV 2, L.P., Global Infrastructure Partners III-C2 Intermediate AIV, L.P. and GIP III Zephyr Friends & Family, LLC
GIP Transaction	On August 31, 2018, NRG transferred its full ownership interest in the Company to Clearway Energy Group LLC and subsequently sold 100% of its interests in Clearway Energy Group LLC, which includes NRG's renewable energy development and operations platform, to an affiliate of GIP. GIP, NRG and the Company also entered into a consent and indemnity agreement in connection with the purchase and sale agreement, which was signed on February 6, 2018
HLBV	Hypothetical Liquidation at Book Value
LIBOR	London Inter-Bank Offered Rate
March 2017 Drop Down Assets	(i) Agua Caliente Borrower 2 LLC, which owns a 16% interest (approximately 31% of NRG's 51% interest) in the Agua Caliente solar farm and (ii) NRG's 100% ownership in the Class A equity interests in the Utah Solar Portfolio (defined below), both acquired by the Company on March 27, 2017
MMBtu	Million British Thermal Units
MW	Megawatts
MWh	Saleable megawatt hours, net of internal/parasitic load megawatt-hours
MWt	Megawatts Thermal Equivalent
Net Exposure	Counterparty credit exposure to Clearway Energy, Inc. net of collateral
NOLs	Net Operating Losses
NPPD	Nebraska Public Power District
NRG	NRG Energy, Inc.
NRG TSA	Transition Services Agreement, dated as of August 31, 2018, by and between NRG and the Company
OCL	Other comprehensive loss
O&M	Operation and Maintenance
PG&E	Pacific Gas and Electric Company
PG&E Bankruptcy	On January 29, 2019, PG&E Corporation and Pacific Gas and Electric Company filed voluntary petitions for relief under the Bankruptcy Code in the Bankruptcy Court. On July 1, 2020, PG&E emerged from bankruptcy
PPA	Power Purchase Agreement
PTC	Production Tax Credit
RENOM	Clearway Renewable Operation & Maintenance LLC
RPV Holdco	RPV Holdco 1 LLC
RTO	Regional Transmission Organization
SEC	U.S. Securities and Exchange Commission
Senior Notes	Collectively, the 2025 Senior Notes, the 2026 Senior Notes and the 2028 Senior Notes

5

SPP	Solar Power Partners
Tax Act	Tax Cuts and Jobs Act of 2017
Thermal Business	The Company's thermal business, which consists of thermal infrastructure assets that provide steam, hot water and/or chilled water, and in some instances electricity, to commercial businesses, universities, hospitals and governmental units
TSA	Transition Services Agreement
UPMC Thermal Project	The University of Pittsburgh Medical Center Thermal Project, a 73 MWt district energy system that allows ECP to provide steam, chilled water and 7.5 MW of emergency backup power service to UPMC
U.S.	United States of America
Utah Solar Portfolio	Collection consists of Four Brothers Solar, LLC, Granite Mountain Holdings, LLC, and Iron Springs Holdings, LLC, which are equity investments owned by Four Brothers Capital, LLC, Granite Mountain Capital, LLC, and Iron Springs Capital, LLC, respectively, and are part of the March 2017 Drop Down Assets acquisition that closed on March 27, 2017
Utility Scale Solar	Solar power projects, typically 20 MW or greater in size (on an alternating current, or AC, basis), that are interconnected into the transmission or distribution grid to sell power at a wholesale level
VaR	Value at Risk
VIE	Variable Interest Entity
Wind TE Holdco	Wind TE Holdco LLC, an 814 net MW portfolio of twelve wind projects

6

PART I - FINANCIAL INFORMATION

ITEM 1 — FINANCIAL STATEMENTS

CLEARWAY ENERGY, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

	Three months ended June 30,				Six months ended June 30,
(In millions, except per share amounts)	2020		2019		2020		2019
Operating Revenues
Total operating revenues	$	329	$	284	$	587	$	501
Operating Costs and Expenses
Cost of operations	87		78		180		160
Depreciation, amortization and accretion	99		90		201		176
Impairment losses	—		19		—		19
General and administrative	12		7		21		13
Transaction and integration costs	—		1		1		2
Development costs	1		2		2		3
Total operating costs and expenses	199		197		405		373
Operating Income	130		87		182		128
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	16		11		3		14
Gain on sale of unconsolidated affiliate	49		—		49		—
Other income, net	—		1		2		4
Loss on debt extinguishment	—		(1)		(3)		(1)
Interest expense	(93)		(130)		(260)		(231)
Total other expense, net	(28)		(119)		(209)		(214)
Income (Loss) Before Income Taxes	102		(32)		(27)		(86)
Income tax expense (benefit)	26		4		4		(3)
Net Income (Loss)	76		(36)		(31)		(83)
Less: Income (loss) attributable to noncontrolling interests and redeemable interests	29		(12)		(49)		(39)
Net Income (Loss) Attributable to Clearway Energy, Inc.	$	47	$	(24)	$	18	$	(44)
Earnings (Losses) Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders
Weighted average number of Class A common shares outstanding - basic and diluted	35		35		35		35
Weighted average number of Class C common shares outstanding - basic and diluted	80		73		79		73
Earnings (Losses) per Weighted Average Class A and Class C Common Share - Basic and Diluted	$	0.41	$	(0.22)	$	0.16	$	(0.41)
Dividends Per Class A Common Share	$	0.21	$	0.20	$	0.42	$	0.40
Dividends Per Class C Common Share	$	0.21	$	0.20	$	0.42	$	0.40

See accompanying notes to consolidated financial statements.

7

CLEARWAY ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Unaudited)

	Three months ended June 30,				Six months ended June 30,
(In millions)	2020		2019		2020		2019
Net Income (Loss)	$	76	$	(36)	$	(31)	$	(83)
Other Comprehensive Income (Loss)
Unrealized gain (loss) on derivatives, net of income tax expense (benefit) of $1, $0, $(1), $0	4		5		(8)		3
Other comprehensive income (loss)	4		5		(8)		3
Comprehensive Income (Loss)	80		(31)		(39)		(80)
Less: Comprehensive income (loss) attributable to noncontrolling interests and redeemable interests	31		(10)		(53)		(38)
Comprehensive Income (Loss) Attributable to Clearway Energy, Inc.	$	49	$	(21)	$	14	$	(42)

See accompanying notes to consolidated financial statements.

8

CLEARWAY ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(In millions, except shares)	June 30, 2020		December 31, 2019
ASSETS	(unaudited)
Current Assets
Cash and cash equivalents	$	175	$	155
Restricted cash	241		262
Accounts receivable — trade	161		116
Accounts receivable — affiliate	—		2
Inventory	41		40
Prepayments and other current assets	36		33
Total current assets	654		608
Property, plant and equipment, net	6,256		6,063
Other Assets
Equity investments in affiliates	971		1,183
Intangible assets, net	1,393		1,428
Deferred income taxes	95		92
Right of use assets, net	257		223
Other non-current assets	110		103
Total other assets	2,826		3,029
Total Assets	$	9,736	$	9,700
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Current portion of long-term debt	$	357	$	1,824
Accounts payable — trade	41		74
Accounts payable — affiliate	21		31
Derivative instruments	41		16
Accrued interest expense	55		41
Accrued expenses and other current liabilities	40		71
Total current liabilities	555		2,057
Other Liabilities
Long-term debt	6,377		4,956
Derivative instruments	192		76
Long-term lease liabilities	260		227
Other non-current liabilities	120		121
Total non-current liabilities	6,949		5,380
Total Liabilities	7,504		7,437
Commitments and Contingencies
Stockholders' Equity
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued	—		—
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 200,678,701 shares issued and outstanding (Class A 34,599,645, Class B 42,738,750, Class C 80,601,556, Class D 42,738,750) at June 30, 2020 and 198,819,999 shares issued and outstanding (Class A 34,599,645, Class B 42,738,750, Class C 78,742,854, Class D 42,738,750) at December 31, 2019	1		1
Additional paid-in capital	1,934		1,936
Accumulated deficit	(54)		(72)
Accumulated other comprehensive loss	(19)		(15)
Noncontrolling interest	370		413
Total Stockholders' Equity	2,232		2,263
Total Liabilities and Stockholders' Equity	$	9,736	$	9,700

See accompanying notes to consolidated financial statements.

9

CLEARWAY ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Six months ended June 30,
	2020		2019
	(In millions)
Cash Flows from Operating Activities
Net loss	$	(31)	$	(83)
Adjustments to reconcile net loss to net cash provided by operating activities:
Equity in earnings of unconsolidated affiliates	(3)		(14)
Distributions from unconsolidated affiliates	10		22
Depreciation, amortization and accretion	201		176
Amortization of financing costs and debt discounts	8		7
Amortization of intangibles and out-of-market contracts	45		35
Loss on debt extinguishment	3		1
Right-of-use asset amortization	(1)		3
Gain on sale of unconsolidated affiliate	(49)		—
Impairment losses	—		19
Changes in deferred income taxes	4		(3)
Changes in derivative instruments	100		70
Loss on disposal of asset components	—		7
Cash used in changes in other working capital
Changes in prepaid and accrued liabilities for tolling agreements	(77)		(60)
Changes in other working capital	(26)		(30)
Net Cash Provided by Operating Activities	184		150
Cash Flows from Investing Activities
Acquisitions	—		(100)
Partnership interest acquisition	—		(6)
Buyout of Wind TE Holdco noncontrolling interest	—		(19)
Consolidation of DGPV Holdco 3 LLC	17		—
Capital expenditures	(83)		(96)
Return of investment from unconsolidated affiliates	23		17
Investments in unconsolidated affiliates	(10)		(9)
Proceeds from sale of assets	90		—
Insurance proceeds	3		—
Other	—		2
Net Cash Provided by (Used in) Investing Activities	40		(211)
Cash Flows from Financing Activities
Net contributions (distributions) from noncontrolling interests	154		(11)
Buyout of Repowering Partnership II LLC noncontrolling interest	(70)		—
Net proceeds from the issuance of common stock	38		—
Payments of dividends and distributions	(84)		(77)
Payments of debt issuance costs	(2)		(15)
Proceeds from the revolving credit facility	265		22
Payments for the revolving credit facility	(265)		(22)
Proceeds from the issuance of long-term debt	286		493
Payments for long-term debt	(547)		(616)
Net Cash Used in Financing Activities	(225)		(226)
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(1)		(287)
Cash, Cash Equivalents and Restricted Cash at beginning of period	417		583
Cash, Cash Equivalents and Restricted Cash at end of period	$	416	$	296

See accompanying notes to consolidated financial statements.

10

CLEARWAY ENERGY, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

For the Six Months Ended June 30, 2020

(Unaudited)

(In millions)	Preferred Stock		Common Stock		Additional Paid-In Capital		Accumulated Deficit		Accumulated Other Comprehensive Loss		Noncontrolling Interest		Total Stockholders' Equity
Balances at December 31, 2019	$	—	$	1	$	1,936	$	(72)	$	(15)	$	413	$	2,263
Net loss	—		—		—		(29)		—		(78)		(107)
Unrealized loss on derivatives, net of tax	—		—		—		—		(6)		(6)		(12)
Contributions from CEG, cash	—		—		—		—		—		4		4
Contributions from tax equity interests, net of distributions, cash	—		—		—		—		—		150		150
Net proceeds from the issuance of common stock under the ATM Program	—		—		10		—		—		—		10
Distributions to tax equity investors, non-cash	—		—		—		—		—		(2)		(2)
Common stock dividends and distributions to CEG	—		—		(24)		—		—		(18)		(42)
Balances at March 31, 2020	$	—	$	1	$	1,922	$	(101)	$	(21)	$	463	$	2,264
Net income	—		—		—		47		—		29		76
Unrealized gain on derivatives, net of tax	—		—		—		—		2		2		4
Contributions from CEG, non-cash	—		—		—		—		—		8		8
Contributions from CEG, cash	—		—		—		—		—		2		2
Distributions to tax equity interests, net of contributions, cash.	—		—		—		—		—		(3)		(3)
Consolidation of DGPV Holdco 3	—		—		—		—		—		(43)		(43)
Buyout of Repowering Partnership II LLC noncontrolling interest	—		—		—		—		—		(70)		(70)
Stock-based compensation	—		—		1		—		—		—		1
Non-cash adjustment for change in tax basis	—		—		7		—		—		—		7
Net proceeds from the issuance of common stock under the ATM Program	—		—		28		—		—		—		28
Common stock dividends and distributions to CEG	—		—		(24)		—		—		(18)		(42)
Balances at June 30, 2020	$	—	$	1	$	1,934	$	(54)	$	(19)	$	370	$	2,232

11

CLEARWAY ENERGY, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

For the Six Months Ended June 30, 2019

(Unaudited)

(In millions)	Preferred Stock		Common Stock		Additional Paid-In Capital		Accumulated Deficit		Accumulated Other Comprehensive Loss		Noncontrolling Interest		Total Stockholders' Equity
Balances at December 31, 2018	$	—	$	1	$	1,897	$	(58)	$	(18)	$	402	$	2,224
Net loss	—		—		—		(20)		—		(27)		(47)
Unrealized loss on derivatives, net of tax	—		—		—		—		(1)		(1)		(2)
Buyout of Wind TE Holdco noncontrolling interest	—		—		(5)		—		—		(14)		(19)
Contributions from tax equity interests, net of distributions, cash	—		—		—		—		—		19		19
Contributions from CEG for Oahu Partnership, non-cash	—		—		—		—		—		12		12
Cumulative effect of change in the accounting principle	—		—		—		(2)		—		(1)		(3)
Common stock dividends and distributions to CEG	—		—		(22)		—		—		(17)		(39)
Balances at March 31, 2019	$	—	$	1	$	1,870	$	(80)	$	(19)	$	373	$	2,145
Net loss	—		—		—		(24)		—		(12)		(36)
Unrealized gain on derivatives, net of tax	—		—		—		—		3		2		5
Distributions to noncontrolling interests, net of contributions, cash	—		—		—		—		—		(30)		(30)
Contributions from CEG for Kawailoa, Repowering Partnerships, non-cash	—		—		—		—		—		6		6
Stock-based compensation	—		—		1		(1)		—		—		—
Non-cash adjustment for change in tax basis of assets	—		—		2		—		—		—		2
Common stock dividends and distributions to CEG	—		—		(21)		—		—		(17)		(38)
Balances at June 30, 2019	$	—	$	1	$	1,852	$	(105)	$	(16)	$	322	$	2,054

12

CLEARWAY ENERGY, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 — Nature of Business

Clearway Energy, Inc., together with its consolidated subsidiaries, or the Company, is a publicly-traded energy infrastructure investor in and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by GIP III Zephyr Acquisition Partners, L.P. through its portfolio company, CEG. GIP is an independent fund manager that invests in infrastructure assets in energy and transport sectors.

The Company’s environmentally-sound asset portfolio includes over 5,991 MW of wind, solar and natural gas-fired power generation facilities. Through this diversified and contracted portfolio, the Company endeavors to provide its investors with stable and growing dividend income. Nearly all of these assets sell substantially all of their output pursuant to long-term offtake agreements with creditworthy counterparties. The weighted average remaining contract duration of these offtake agreements was approximately 13 years as of June 30, 2020 based on CAFD. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,453 net MWt and electric generation capacity of 36 net MW. These thermal infrastructure assets provide steam, hot and/or chilled water, and, in some instances, electricity to commercial businesses, universities, hospitals and governmental units in multiple locations, principally through long-term contracts or pursuant to rates regulated by state utility commissions.

The Company consolidates the results of Clearway Energy LLC through its controlling interest, with CEG's interest shown as noncontrolling interest in the financial statements. The holders of the Company's outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from Clearway Energy LLC through its ownership of Clearway Energy LLC Class B and Class D units.

As a result of the Class C common stock issuance under the ATM Program during the six months ended June 30, 2020, the Company owns 57.41% of the economic interests of Clearway Energy LLC, with CEG retaining 42.59% of the economic interests of Clearway Energy LLC as of June 30, 2020. For further discussion, see Note 9, Changes in Capital Structure.

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The following table represents the structure of the Company as of June 30, 2020:

Basis of Presentation

The accompanying unaudited interim consolidated financial statements have been prepared in accordance with the SEC’s regulations for interim financial information and with the instructions to Form 10-Q. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. The following notes should be read in conjunction with the accounting policies and other disclosures as set forth in the notes to the consolidated financial statements included in the Company's 2019 Form 10-K. Interim results are not necessarily indicative of results for a full year.

In the opinion of management, the accompanying unaudited interim consolidated financial statements contain all material adjustments consisting of normal and recurring accruals necessary to present fairly the Company's consolidated financial position as of June 30, 2020, and the results of operations, comprehensive income (loss) and cash flows for the six months ended June 30, 2020 and 2019.

PG&E Bankruptcy Update

During 2019, PG&E, one of the Company's largest customers, filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the Northern District of California, or the Bankruptcy Court. On January 31, 2020, PG&E filed with the Bankruptcy Court a Chapter 11 plan of reorganization, as amended, or the PG&E Plan. On June 20, 2020, the Bankruptcy Court confirmed the PG&E Plan, which provided for PG&E to assume all of its PPAs with the Company. On July 1, 2020, PG&E emerged from bankruptcy and assumed the Company's contracts without modification. In addition, PG&E paid to the Company's applicable projects the portion of the invoices corresponding to the electricity delivered for the period between January 1 and January 28, 2019. These invoices related to the pre-petition period services and any payment therefore required the approval by the Bankruptcy Court. A description of changes to the financial statements resulting from PG&E's emergence from bankruptcy is noted below in Note 2, Summary of Significant Accounting Policies, Note 5, Fair Value of Financial Instruments and Note 7, Long-term Debt.

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Note 2 — Summary of Significant Accounting Policies

Use of Estimates

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

Cash and Cash Equivalents, and Restricted Cash

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase. Cash and cash equivalents held at project subsidiaries was $116 million and $125 million as of June 30, 2020 and December 31, 2019, respectively. After PG&E emerged from bankruptcy on July 1, 2020, $50 million of cash distributions were paid out of distribution reserve accounts at subsidiaries affected by the PG&E Bankruptcy to Clearway Energy Operating LLC as of July 31, 2020.

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

	June 30, 2020		December 31, 2019
	(In millions)
Cash and cash equivalents	$	175	$	155
Restricted cash	241		262
Cash, cash equivalents and restricted cash shown in the statement of cash flows	$	416	$	417

Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company's projects that are restricted in their use. As of June 30, 2020, these restricted funds were comprised of $80 million designated to fund operating expenses, approximately $20 million designated for current debt service payments, and $56 million restricted for reserves including debt service, performance obligations and other reserves, as well as capital expenditures. The remaining $85 million is held in distributions reserve accounts. As of June 30, 2020, $14 million of cash that was restricted pending the outcome of the PG&E Bankruptcy was reclassified into cash and cash equivalents.

Accumulated Depreciation, Accumulated Amortization

The following table presents the accumulated depreciation included in the property, plant and equipment, net, and accumulated amortization included in intangible assets, net, respectively, as of June 30, 2020 and December 31, 2019:

	June 30, 2020		December 31, 2019
	(In millions)
Property, Plant and Equipment Accumulated Depreciation	$	2,036	$	1,880
Intangible Assets Accumulated Amortization	439		394

Dividends to Class A and Class C common stockholders

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.

On July 30, 2020, the Company declared quarterly dividends on its Class A common stock and Class C common stock of $0.3125 per share payable on September 15, 2020, to stockholders of record as of September 1, 2020.

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Noncontrolling Interests

Clearway Energy LLC Distributions to CEG

The following table lists distributions paid to CEG during the period ended June 30, 2020 on Clearway Energy LLC's Class B and D units:

	Second Quarter 2020		First Quarter 2020
Distributions per Class B Unit	$	0.21	$	0.21
Distributions per Class D Unit	$	0.21	$	0.21

On July 30, 2020, Clearway Energy LLC declared a distribution on its Class B and Class D units of $0.3125 per unit payable on September 15, 2020 to unit holders of record as of September 1, 2020.

Revenue Recognition

Revenue from Contracts with Customers

The Company applies the guidance in ASC 606, Revenue from Contracts with Customers, or Topic 606, when recognizing revenue associated with its contracts with customers. The Company's policies with respect to its various revenue streams are detailed below. In general, the Company applies the invoicing practical expedient to recognize revenue for the revenue streams detailed below, except in circumstances where the invoiced amount does not represent the value transferred to the customer.

Thermal Revenues

Steam and chilled water revenue is recognized as the Company transfers the product to the customer, based on customer usage as determined by meter readings taken at month-end. Some locations read customer meters throughout the month and recognize estimated revenue for the period between meter read date and month-end. For thermal contracts, the Company’s performance obligation to deliver steam and chilled water is satisfied over time and revenue is recognized based on the invoiced amount. The Thermal Business subsidiaries collect, and remit state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes are presented on a net basis in the income statement.

As contracts for steam and chilled water are long-term contracts, the Company has performance obligations under these contracts that have not yet been satisfied. These performance obligations have transaction prices that are both fixed and variable, and which vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the Company cannot accurately estimate the amount of its unsatisfied performance obligations as it will vary based on customer usage, which will depend on factors such as weather and customer activity.

Power Purchase Agreements

The majority of the Company’s revenues are obtained through PPAs or other contractual agreements. Energy, capacity and where applicable, renewable attributes, from the majority of the Company’s renewable energy assets and certain conventional energy plants is sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer. The majority of these PPAs are accounted for as leases. Previously ASC 840, and currently ASC 842, requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. Management's judgment is required in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or capital lease.

Renewable Energy Credits

Renewable energy credits, or RECs, are usually sold through long-term PPAs. Revenue from the sale of self-generated RECs is recognized when the related energy is generated and simultaneously delivered even in cases where there is a certification lag as it has been deemed to be perfunctory.

In a bundled contract to sell energy, capacity and/or self-generated RECs, all performance obligations are deemed to be delivered at the same time and hence, timing of recognition of revenue for all performance obligations is the same and occurs over time. In such cases, it is often unnecessary to allocate transaction price to multiple performance obligations.

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Disaggregated Revenues  

The following tables represent the Company’s disaggregation of revenue from contracts with customers along with the reportable segment for each category for the three and six months ended June 30, 2020 and 2019 respectively:

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	1	$	195	$	22	$	218
Capacity revenue(a)	112		—		12		124
Contract amortization	(6)		(16)		—		(22)
Other revenue	—		4		8		12
Mark-to-market for economic hedges	—		(3)		—		(3)
Total operating revenue	107		180		42		329
Less: Mark-to-market for economic hedges	—		3		—		3
Less: Lease revenue	(113)		(181)		—		(294)
Less: Contract amortization	6		16		—		22
Total revenue from contracts with customers	$	—	$	18	$	42	$	60

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	181	$	—	$	182
Capacity revenue	112		—		—		112
Total	$	113	$	181	$	—	$	294

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	3	$	320	$	50	$	373
Capacity revenue(a)	219		—		26		245
Contract amortization	(12)		(31)		(1)		(44)
Other revenue	—		6		15		21
Mark-to-market for economic hedges	—		(8)		—		(8)
Total operating revenue	210		287		90		587
Less: Mark-to-market for economic hedges	—		8		—		8
Less: Lease revenue	(222)		(296)		(1)		(519)
Less: Contract amortization	12		31		1		44
Total revenue from contracts with customers	$	—	$	30	$	90	$	120

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	3	$	296	$	1	$	300
Capacity revenue	219		—		—		219
Total	$	222	$	296	$	1	$	519

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	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	1	$	166	$	26	$	193
Capacity revenue(a)	85		—		14		99
Contract amortization	(2)		(15)		—		(17)
Other revenue	—		2		7		9
Total operating revenue	84		153		47		284
Less: Lease revenue	(86)		(157)		(1)		(244)
Less: Contract amortization	2		15		—		17
Total revenue from contracts with customers	$	—	$	11	$	46	$	57

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	157	$	1	$	159
Capacity revenue	85		—		—		85
Total	$	86	$	157	$	1	$	244

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	2	$	274	$	58	$	334
Capacity revenue(a)	164		—		27		191
Contract amortization	(3)		(30)		(1)		(34)
Mark-to-market for economic hedges	—		(7)		—		(7)
Other revenue	—		4		13		17
Total operating revenue	163		241		97		501
Less: Mark-to-market for economic hedges	—		7		—		7
Less: Lease revenue	(166)		(256)		(1)		(423)
Less: Contract amortization	3		30		1		34
Total revenue from contracts with customers	$	—	$	22	$	97	$	119

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	2	$	256	$	1	$	259
Capacity revenue	164		—		—		164
Total	$	166	$	256	$	1	$	423

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Contract Amortization

Assets and liabilities recognized from power sales agreements assumed through acquisitions related to the sale of electric capacity and energy in future periods for which the fair value has been determined to be significantly less (more) than market are amortized to revenue over the term of each underlying contract based on actual generation and/or contracted volumes or on a straight-line basis, where applicable.

Contract Balances

The following table reflects the contract assets and liabilities included on the Company’s balance sheet as of June 30, 2020:

(In millions)
Accounts receivable, net - Contracts with customers	$	39
Accounts receivable, net - Leases	122
Total accounts receivable, net	$	161

Recently Issued Accounting Standards Adopted in 2020

In March 2020, the FASB issued ASU 2020-4, Facilitation of the Effects of Reference Rate Reform on Financial Reporting. The amendments provide for optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria is met. These amendments apply only to contracts that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. The guidance is effective for all entities as of March 12, 2020 through December 31, 2022. The Company intends to apply the amendments to all its eligible contract modifications where applicable.

Recently Issued Accounting Standards Not Yet Adopted

In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. The amendments in this ASU simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740, Income Taxes. The amendments also improve consistent application of and simplify GAAP for other areas of Topic 740 by clarifying and amending existing guidance. The guidance is effective January 1, 2021, with early adoption permitted. The Company does not expect the effect of the new guidance to be material on its consolidated financial statements.

Reclassification

Certain prior year amounts have been reclassified for comparative purposes.

Note 3 — Acquisition and Dispositions

2019 Acquisition

Duquesne University District Energy System Acquisition — On May 1, 2019, the Company, through its indirect subsidiary ECP Uptown Campus LLC, acquired the Duquesne University district energy system, totaling 87 combined MWt, located in Pittsburgh, PA. As part of the acquisition, Duquesne University entered into a 40-year Energy Services Agreement through which ECP Uptown Campus LLC will fulfill the university's electricity, chilled water and steam requirements in exchange for monthly capacity payments. The transaction is reflected in the Company's Thermal segment. The total investment for the project was approximately $107 million.

2020 Dispositions

Sale of RPV Holdco 1 LLC — On May 14, 2020, the Company sold its interests in RPV Holdco 1 LLC, or RPV Holdco, to a third party for net proceeds of approximately $75 million. The Company previously accounted for its interest in RPV Holdco as an equity method investment. The sale of the investment resulted in a gain of approximately $49 million.

Sale of Energy Center Dover LLC and Energy Center Smyrna LLC Assets — On March 3, 2020, the Company, through Clearway Thermal LLC, sold 100% of its interests in Energy Center Dover LLC and Energy Center Smyrna LLC to DB Energy Assets, LLC.

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Note 4 — Investments Accounted for by the Equity Method and Variable Interest Entities

Entities that are Consolidated

The Company has a controlling financial interest in certain entities which have been identified as VIEs under ASC 810, Consolidations, or ASC 810. These arrangements are primarily related to tax equity arrangements entered into with third parties in order to monetize certain tax credits associated with wind and solar facilities, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the consolidated financial statements included in the Company's 2019 Form 10-K.

Summarized financial information for the Company's consolidated VIEs consisted of the following as of June 30, 2020:

(In millions)	Oahu Solar Partnership		Kawailoa Partnership		Elbow Creek TE Holdco		Wildorado TE Holdco		DGPV Holdco 3		Alta TE Holdco		Spring Canyon		Buckthorn Renewables LLC		Other (a)
Other current and non-current assets	$	26	$	23	$	10	$	19	$	63	$	61	$	3	$	3	$	5
Property, plant and equipment	183		144		104		249		330		369		84		211		8
Intangible assets	—		—		1		—		1		231		—		—		—
Total assets	209		167		115		268		394		661		87		214		13
Current and non-current liabilities	127		117		26		12		281		44		6		7		3
Total liabilities	127		117		26		12		281		44		6		7		3
Noncontrolling interest	30		40		75		109		6		44		35		66		—
Net assets less noncontrolling interests	$	52	$	10	$	14	$	147	$	107	$	573	$	46	$	141	$	10

^(a) Other is comprised of Crosswinds and Hardin projects.

The discussion below describes material changes to VIEs during the six months ended June 30, 2020.

DGPV Holdco 3 LLC

DGPV Holdco 3 owns approximately 113 MW of distributed solar capacity, based on cash to be distributed, with a weighted average remaining contract life of approximately 21 years as of June 30, 2020. On May 29, 2020, the final construction projects for DGPV Holdco 3 were placed in service which resulted in a reconsideration event for consolidation of the entity. Upon the reconsideration event, the Company determined that it was the primary beneficiary of DGPV Holdco 3, as it is entitled to 99% of allocations of income and cash distributions from the entity. As such, effective on May 29, 2020, the Company consolidates DGPV Holdco 3, and shows the interest owned by CEG as noncontrolling interest. DGPV Holdco 3 owns an interest in two tax equity funds with tax equity investors, both of which are consolidated by DGPV Holdco 3, and the interests owned by the tax equity investors are shown as noncontrolling interests. The Company removed its investment in DGPV Holdco 3 of $155 million as of May 29, 2020 and recorded the difference between the net assets consolidated and the investment balance as a reduction to noncontrolling interests.

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The following table shows the balances that were consolidated effective on May 29, 2020:

(In millions)	May 29, 2020
Current assets	$	32
Property, plant and equipment	330
Intangible assets	1
Other non-current assets	37
Total assets	$	400
Debt	206
Other current and non-current liabilities	84
Total liabilities	$	290
Noncontrolling interests and redeemable noncontrolling interests	6
Net assets less noncontrolling interests	$	104

Prior to the reconsideration event described above, the Company invested $10 million of cash in DGPV Holdco 3 during the six months ended June 30, 2020.

Repowering Partnership II LLC

On May 11, 2020, the Company acquired CEG's interest in Repowering Partnership II LLC, for cash consideration of $70 million. Repowering Partnership II LLC is no longer a VIE and subsequent to the acquisition, is a wholly-owned subsidiary of the Company. Repowering Partnership II LLC continues to own interests in two VIEs, Wildorado Repowering Tax Equity Holdco LLC, or Wildorado TE Holdco, and Elbow Creek Repowering Tax Equity Holdco LLC, or Elbow Creek TE Holdco. The Company removed the related noncontrolling interest balance of $8 million and recorded the difference between the cash paid and the noncontrolling interest balance removed as a reduction to noncontrolling interests.

On February 7, 2020, a third party tax equity investor purchased 100% of the Class A membership interests in Wildorado TE Holdco, for $148 million. In addition, the Company contributed $112 million to Wildorado TE Holdco. The combined proceeds were used to repay construction debt under the Repowering Partnership Holdco credit agreement, as described in Note 7, Long-term Debt. The third party tax equity investor, or Wildorado Investor, will receive 99% of allocations of taxable income and other items until the Wildorado Investor obtains a specified return on its initial investment, or the last day of the PTC period, whichever occurs sooner. At such time, the allocations to the Wildorado Investor will change to 5%. Until such time, the Wildorado Investor will receive a variable percentage of cash distributions. Wildorado TE Holdco is a VIE and the Repowering Partnership II LLC is the primary beneficiary through its position as managing member. As a result, the Company consolidates Wildorado TE Holdco, with the Wildorado Investor's interest shown as noncontrolling interest. In connection with the Wildorado TE Holdco closing, the allocations of income at Repowering Partnership II LLC changed to 60.14% for Wind TE Holdco LLC (the Company member) and 39.86% for CWSP Wildorado Elbow Holding LLC (the CEG member). As noted above, CEG no longer has an interest in Repowering Partnership II LLC as of June 30, 2020.

The Company utilizes the HLBV method to determine the net income or loss allocated to tax equity noncontrolling interest. The Company recorded a loss of $8 million and $36 million attributable to the noncontrolling interest of Wildorado TE Holdco for the three and six months ending June 30, 2020 and recorded a loss of $6 million and $8 million attributable to the noncontrolling interest of Elbow Creek TE Holdco for the three and six months ending June 30, 2020, respectively.

Entities that are not Consolidated

The Company has interests in entities that are considered VIEs under ASC 810, but for which it is not considered the primary beneficiary. The Company accounts for its interests in these entities under the equity method of accounting, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the consolidated financial statements included in the Company's 2019 Form 10-K.

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The Company's maximum exposure to loss as of June 30, 2020 is limited to its equity investment in the unconsolidated entities, as further summarized in the table below:

Name	Economic Interest	Investment Balance
		(In millions)
Utah Solar Portfolio (a)	50%	$	276
Desert Sunlight (b)	25%	276
Agua Caliente Solar (b)	16%	99
GenConn	50%	92
DGPV Holdco 1 LLC (c)	95%	82
DGPV Holdco 2 LLC (c)	95%	63
San Juan Mesa	75%	45
Elkhorn Ridge	66.7%	42
Avenal (b)	50%	(4)
		$	971

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

^(b) Entities that have PPAs with PG&E. For further update on PG&E Bankruptcy see Note 1— Nature of Business.

^(c) Economic interest based on cash to be distributed. DGPV Holdco 1 LLC and DGPV Holdco 2 LLC, are tax equity structures and VIEs.

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

	Three months ended June 30,				Six months ended June 30,
(In millions)	2020		2019		2020		2019
Income Statement Data:
DGPV Holdco 3 (a)
Operating revenue	$	7	$	8	$	14	$	12
Operating income	4		4		6		5
Net income (loss)	4		9		(12)		9
RPV Holdco (b)
Operating revenue	2		3		6		7
Operating income	—		—		—		1
Net (loss) income	—		(2)		3		(3)
GenConn
Operating revenue	15		15		29		31
Operating income	7		7		13		14
Net income	4		5		8		9
Desert Sunlight
Operating revenue	59		57		95		92
Operating income	42		37		63		53
Net income	25		16		28		20
Other (c)
Operating revenue	81		79		136		131
Operating income	40		34		52		44
Net income	$	32	$	20	$	22	$	16

^(a) Year to date as of the reconsideration event on May 29, 2020.

^(b) Year to date as of the sale on May 14, 2020 as described in Note 3, Acquisition and Dispositions.

^(c) Includes Agua Caliente, DGPV Holdco 1, DGPV Holdco 2, Elkhorn Ridge, Utah Solar Portfolio and San Juan Mesa.

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	As of June 30, 2020		As of December 31, 2019
Balance Sheet Data:	(In millions)
DGPV Holdco 3 (a)
Current assets	$	—	$	39
Non-current assets	—		371
Current liabilities	—		61
Non-current liabilities	—		216
Redeemable noncontrolling interest	—		(1)
RPV Holdco (a)
Current assets	—		2
Non-current assets	—		162
Current liabilities	—		1
Non-current liabilities	—		8
Redeemable noncontrolling interest	—		31
GenConn
Current assets	36		37
Non-current assets	352		342
Current liabilities	14		16
Non-current liabilities	190		176
Desert Sunlight
Current assets	261		209
Non-current assets	1,271		1,296
Current liabilities	545		545
Non-current liabilities	482		484
Other (b)
Current assets	275		220
Non-current assets	2,807		2,879
Current liabilities	71		785
Non-current liabilities	991		277

^(a) As of June 30, 2020, these are no longer equity method investments

^(b) Includes Agua Caliente, DGPV Holdco 1, DGPV Holdco 2, Elkhorn Ridge, Utah Solar Portfolio and San Juan Mesa.

Note 5 — Fair Value of Financial Instruments

Fair Value Accounting under ASC 820

ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

•Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date.

•Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

•Level 3—unobservable inputs for the asset or liability only used when there is little, if any, market activity for the asset or liability at the measurement date.

In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement.

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

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

	As of June 30, 2020				As of December 31, 2019
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Long-term debt, including current portion (a)	$	6,813	$	6,917	$	6,858	$	6,957

^(a) Excludes net debt issuance costs, which are recorded as a reduction to long-term debt on the Company's consolidated balance sheets.

The fair value of the Company's publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of non-publicly traded long-term debt of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy. The following table presents the level within the fair value hierarchy for long-term debt, including current portion as of June 30, 2020 and December 31, 2019:

	As of June 30, 2020				As of December 31, 2019
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	1,849	$	5,068	$	1,736	$	5,221

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Recurring Fair Value Measurements

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

	As of June 30, 2020				As of December 31, 2019
	Fair Value (a)				Fair Value (a)
(In millions)	Level 2		Level 3		Level 2		Level 3
Derivative liabilities:
Commodity contracts	$	1	$	17	$	—	$	9
Interest rate contracts	215		—		83		—
Total liabilities	$	216	$	17	$	83	$	9

^(a) There were no derivative assets classified as Level 1, Level 2 or Level 3 and no liabilities classified as Level 1 as of June 30, 2020 and as of December 31, 2019.

The following table reconciles the beginning and ending balances for instruments that are recognized at fair value in the condensed consolidated financial statements using significant unobservable inputs:

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
(In millions)	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)				Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
Beginning balance	$	(14)	$	(7)	$	(9)	$	—
Total losses for the period included in earnings	(3)		—		(8)		—
Purchases	—		—		—		(7)
Ending balance	$	(17)	$	(7)	$	(17)	$	(7)
Change in unrealized losses included in earnings for derivatives held as of June 30, 2020	$	(3)			$	(8)

Derivative Fair Value Measurements

The Company's contracts are non-exchange-traded and valued using prices provided by external sources. For some of the Company’s energy contracts, management receives quotes from multiple sources. To the extent that multiple quotes are received, the prices reflect the average of the bid-ask mid-point prices obtained from all sources believed to provide the most liquid market for the commodity. The remainder of the assets and liabilities represent contracts for which external sources or observable market quotes are not available. These contracts are valued based on various valuation techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of the observable market data with similar characteristics. As of June 30, 2020, contracts valued with prices provided by models and other valuation techniques make up 7% of derivative liabilities.

The Company’s significant position classified as Level 3 includes physical power executed in illiquid markets. The significant unobservable inputs used in developing fair value include illiquid power tenors and location pricing, which is derived by extrapolating pricing and as a basis to liquid locations. The tenor pricing and basis spread are based on observable market data when available or derived from historic prices and forward market prices from similar observable markets when not available.

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The following tables quantify the significant unobservable inputs used in developing the fair value of the Company's Level 3 positions as of June 30, 2020:

	June 30, 2020
	Fair Value						Input/Range
	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low	High	Weighted Average
(In millions)
Power Contracts	$	—	$	(17)	Discounted Cash Flow	Forward Market Price (per MWh)	8.71	40.55	16.07

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of June 30, 2020:

Significant Observable Input	Position	Change In Input	Impact on Fair Value Measurement
Forward Market Price Power	Buy	Increase/(Decrease)	Higher/(Lower)
Forward Market Price Power	Sell	Increase/(Decrease)	Lower/(Higher)

The fair value of each contract is discounted using a risk-free interest rate. In addition, a credit reserve is applied to reflect credit risk, which is, for interest rate swaps, calculated based on credit default swaps using the bilateral method. For commodities, to the extent that the net exposure under a specific master agreement is an asset, the Company uses the counterparty’s default swap rate. If the net exposure under a specific master agreement is a liability, the Company uses a proxy of its own default swap rate. For interest rate swaps and commodities, the credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of June 30, 2020, the non-performance reserve was a $13 million gain recorded primarily in interest expense in the consolidated statements of operations. It is possible that future market prices could vary from those used in recording assets and liabilities and such variations could be material.

Concentration of Credit Risk

In addition to the credit risk discussion in Note 2, Summary of Significant Accounting Policies, to the consolidated financial statements included in the Company's 2019 Form 10-K, the following is a discussion of the concentration of credit risk for the Company's financial instruments. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; (ii) monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties.

Counterparty credit exposure includes credit risk exposure under certain long-term agreements, including solar and other PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company estimates the exposure related to these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. The majority of these power contracts are with utilities with strong credit quality and public utility commission or other regulatory support. However, such regulated utility counterparties can be impacted by changes in government regulations or adverse financial conditions, which the Company is unable to predict.

On January 31, 2019, PG&E filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. On June 20, 2020, the Bankruptcy Court confirmed the PG&E Plan, which provided for PG&E to assume all of its PPAs with the Company. On July 1, 2020, PG&E emerged from bankruptcy. The Company had $5 million in accounts receivable due from PG&E for its consolidated projects that was previously recorded to non-current assets, and reclassified to current assets as of June 30, 2020, all of which was received in July of 2020.

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Note 6 — Derivative Instruments and Hedging Activities

This footnote should be read in conjunction with the complete description under Note 7, Accounting for Derivative Instruments and Hedging Activities, to the consolidated financial statements included in the Company's 2019 Form 10-K.

Interest Rate Swaps

The Company enters into interest rate swap agreements in order to hedge the variability of expected future cash interest payments. As of June 30, 2020, the Company had interest rate derivative instruments on non-recourse debt extending through 2043, a portion of which were designated as cash flow hedges. Under the interest rate swap agreements, the Company pays a fixed rate and the counterparties to the agreements pay a variable interest rate.

Energy-Related Commodities

As of June 30, 2020, the Company had energy-related derivative instruments extending through 2029. At June 30, 2020, these contracts were not designated as cash flow or fair value hedges.

Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy of the Company's open derivative transactions broken out by type:

		Total Volume
		June 30, 2020		December 31, 2019
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		2
Power	MWh	(2)		(2)
Interest	Dollars	$	1,965	$	1,788

Fair Value of Derivative Instruments

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

	Fair Value
		Derivative Liabilities
		June 30, 2020		December 31, 2019
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current		$	8	$	3
Interest rate contracts long-term		20		11
Total Derivatives Designated as Cash Flow Hedges		28		14
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current		32		13
Interest rate contracts long-term		155		56
Commodity contracts current		1		—
Commodity contracts long-term		17		9
Total Derivatives Not Designated as Cash Flow Hedges		205		78
Total Derivatives		$	233	$	92

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The Company has elected to present derivative assets and liabilities on the balance sheet on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As of June 30, 2020 and December 31, 2019, there was no outstanding collateral paid or received. The following tables summarize the offsetting of derivatives by the counterparty master agreement level as of June 30, 2020 and December 31, 2019:

As of June 30, 2020	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Commodity contracts:	(In millions)
Derivative liabilities	$	(18)	$	1	$	(17)
Total commodity contracts	(18)		1		(17)
Interest rate contracts:
Derivative liabilities	(215)		(1)		(216)
Total interest rate contracts	(215)		(1)		(216)
Total derivative instruments	$	(233)	$	—	$	(233)

As of December 31, 2019	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Commodity contracts:	(In millions)
Derivative liabilities	$	(9)	$	(1)	$	(10)
Total commodity contracts	(9)		(1)		(10)
Interest rate contracts:
Derivative liabilities	(83)		1		(82)
Total interest rate contracts	(83)		1		(82)
Total derivative instruments	$	(92)	$	—	$	(92)

Accumulated Other Comprehensive Loss

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

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
	(In millions)
Accumulated OCL beginning balance	$	(43)	$	(40)	$	(31)	$	(38)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	1		14		3		17
Mark-to-market of cash flow hedge accounting contracts	3		(9)		(11)		(14)
Accumulated OCL ending balance, net of income tax benefit of $7, $6, $7 and $6, respectively	(39)		(35)		(39)		(35)
Accumulated OCL attributable to noncontrolling interests	(20)		(19)		(20)		(19)
Accumulated OCL attributable to Clearway Energy, Inc.	$	(19)	$	(16)	$	(19)	$	(16)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4	$	(10)			$	(10)

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Impact of Derivative Instruments on the Statements of Operations

Gains and losses related to the Company's derivatives are recorded in the consolidated statements of operations as follows:

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
	(In millions)
Interest Rate Contracts (Interest Expense)	$	(13)	$	(36)	$	(92)	$	(54)
Mark-to-market economic hedging activities (a)	(3)		—		(8)		—

^(a) Relates to long-term power hedge at Elbow Creek Wind Project LLC, or Elbow Creek.

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

See Note 5, Fair Value of Financial Instruments, for a discussion regarding concentration of credit risk.

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Note 7 — Long-term Debt

This note should be read in conjunction with the complete description under Note 10, Long-term Debt, to the consolidated financial statements included in the Company's 2019 Form 10-K. Long-term debt consisted of the following:

	June 30, 2020		December 31, 2019		June 30, 2020, interest rate % (a)	Letters of Credit Outstanding at June 30, 2020
	(In millions, except rates)
2020 Convertible Notes (e)	$	—	$	45	3.250
2024 Senior Notes (b)	—		88		5.375
2025 Senior Notes	600		600		5.750
2026 Senior Notes	350		350		5.000
2028 Senior Notes	850		600		4.750
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (c)	—		—		L+2.00	56
Project-level debt:
Alpine, due 2022 (d)	117		119		L+2.00	8
Alta Wind I-V lease financing arrangements, due 2034 and 2035	816		844		5.696 - 7.015	29
Buckthorn Solar, due 2025	128		129		L+1.750	26
Carlsbad Holdco, due 2038	215		216		4.210	9
Carlsbad Energy Holdings LLC, due 2027 and 2038	582		582		various	81
Chestnut Borrower, LLC, due 2024	110		—		L+2.50	8
CS4 Borrower, due 2026	104		—		L+2.00	4
CVSR, due 2037 (d)	684		696		2.339 - 3.775	—
CVSR Holdco Notes, due 2037 (d)	176		182		4.680	13
Duquesne, due 2059	95		95		4.620	—
El Segundo Energy Center, due 2023	269		303		L+1.75 - L+2.375	138
Energy Center Minneapolis Series D, E, F, G, H Notes, due 2025-2037	327		328		various	—
Laredo Ridge, due 2028	81		84		L+2.125	10
Kansas South, due 2030 (d)	23		24		L+2.25	2
Kawailoa Solar Holdings LLC, due 2026	82		82		L+1.375	15
Marsh Landing, due 2023 (d)	190		206		L+2.125	27
Oahu Solar Holdings LLC, due 2026	91		91		L+1.375	17
Repowering Partnership Holdco LLC, due 2020 (b)	—		228		L+.85	—
South Trent, due 2028	40		43		L+1.350	12
Tapestry, due 2031	149		156		L+1.375	18
Utah Solar Portfolio, due 2022	247		254		L+2.625	13
Viento, due 2023	35		42		L+2.00	14
Walnut Creek, due 2023	161		175		L+1.75	92
Other	286		296		various	34
Subtotal project-level debt:	5,008		5,175
Total debt	6,808		6,858
Less current maturities	(357)		(1,824)
Less net debt issuance costs	(79)		(78)
Add premiums(f)	5		—
Total long-term debt	$	6,377	$	4,956

^(a) As of June 30, 2020, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023 and Kansas South, due 2030 where L+ equals 6 month LIBOR plus x% and Utah Solar Portfolio, where L+ equals 1 month LIBOR plus 2.625%

^(b) Repaid in the first quarter of 2020, as further described below

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

^(d) Entities affected by PG&E Bankruptcy, see further discussion below

^(e) Matured and repaid on June 1, 2020

^(f) Premiums relate to the 2028 Senior Notes

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The financing arrangements listed above contain certain covenants, including financial covenants that the Company is required to be in compliance with during the term of the respective arrangement. As of June 30, 2020, the Company was in compliance with all of the required covenants, other than any covenants impacted by the PG&E Bankruptcy, as discussed below. The discussion below describes material changes to or additions of long-term debt for the six months ended June 30, 2020.

Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility

As of June 30, 2020, the Company had no outstanding borrowings under the revolving credit facility and $56 million in letters of credit outstanding. During the six months ended June 30, 2020, the Company borrowed $265 million under the revolving credit facility, and subsequently repaid $265 million utilizing the proceeds from the issuance of additional 2028 Senior Notes, as described below, and cash on hand.

2028 Senior Notes

On May 21, 2020, the Company completed the issuance of an additional $250 million in aggregate principal amount of its 4.750% Senior Notes due 2028. The 2028 Senior Notes bear interest at 4.75% and mature on March 15, 2028. Interest on the 2028 Senior Notes is payable semi-annually on March 15 and September 15 of each year, and interest payments will commence on September 15, 2020. The 2028 Senior Notes are unsecured obligations of Clearway Energy Operating, LLC and are guaranteed by Clearway Energy, LLC and by certain of Clearway Energy Operating LLC’s wholly owned current and future subsidiaries. The notes were issued at a price of 102% of par plus accrued interest from December 11, 2019. The net proceeds were utilized to repay the $45 million outstanding principal amount of the Company's 2020 Convertible Notes on June 1, 2020, as well as to repay amounts outstanding under the Company’s revolving credit facility and for general corporate purposes.

2024 Senior Notes Redemption

On January 3, 2020, the Company redeemed the $88 million aggregate principal amount of the 2024 Senior Notes that remained outstanding following the Company's tender offer for the 2024 Senior Notes in December 2019. The redemption was effectuated at a premium of 102.7% for a total consideration of $90 million and as a result, the Company recorded a loss on debt extinguishment in the amount of $3 million, which also included the write off of previously deferred financing fees related to the 2024 Senior Notes.

Project - level Debt

PG&E Bankruptcy

As of June 30, 2020, distributions from all PG&E affected projects to Clearway Energy Operating LLC were prohibited under the related debt agreements. On July 1, 2020, PG&E emerged from bankruptcy and assumed the Company's contracts without modification. In addition, PG&E paid to the Company's applicable projects the portion of the invoices corresponding to the electricity delivered between January 1 and January 28, 2019. These invoices related to the pre-petition period services and any payment therefore required the approval of the Bankruptcy Court. The Company has reclassified the related debt to non-current based on its original maturity as of June 30, 2020.

Repowering Partnership Holdco LLC, due 2020

In February 2020, the Company repaid $260 million of construction debt outstanding under the construction loan facility. The repayment was effectuated with the proceeds from the tax equity contributions for Wildorado TE Holdco, as further descried in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities as well as with the contributions by the Company.

Consolidation of DGPV Holdco 3

Upon consolidation of DGPV Holdco 3, as described in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities, the Company consolidates additional non-recourse debt for certain subsidiaries as further described below.

Renew CS4 Borrower LLC, or CS4 Borrower, a consolidated subsidiary of DGPV Holdco 3, is party to a credit agreement for construction loans up to $97.4 million, an investment tax credit bridge loan, or ITC bridge loan, for up to $89.9 million and letter of credit facilities up to $4.9 million. The construction loan and the ITC bridge loan both have an interest rate of LIBOR plus an applicable margin of 2.00% per annum. As of June 30, 2020, all construction loans were converted to term loans and the ITC bridge loans were repaid in connection with tax equity funding. The term loan bears annual interest at a rate of LIBOR plus an applicable margin, which is 2.00% per annum through the third anniversary of the

31

term conversion, and 2.25% per annum thereafter through the maturity date in June 2026. The borrowings are secured by the membership interests in the project companies.

Chestnut Borrower LLC, a consolidated subsidiary of DGPV Holdco 3, is party to a credit agreement for term loans of up to $120.3 million and letters of credit of up to $7.9 million. The loans bear annual interest at a rate of LIBOR plus an applicable margin, which is 2.50% per annum through the fifth anniversary of the financial closing date, or July 2022, and 2.75% per annum thereafter through the maturity date in April 2024. The borrowings are secured by the membership interests in the project companies.

Note 8 — Earnings Per Share

Basic earnings per common share is computed by dividing net income by the weighted average number of common shares outstanding. Shares issued during the year are weighted for the portion of the year that they were outstanding. Diluted earnings per share is computed in a manner consistent with that of basic earnings per share while giving effect to all potentially dilutive common shares that were outstanding during the period.

The reconciliation of Clearway Energy, Inc.'s basic and diluted earnings per share is shown in the following tables:

	Three months ended June 30,
	2020				2019
(In millions, except per share data) (a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$	14	$	33	$	(8)	$	(16)
Weighted average number of common shares outstanding — basic and diluted	35		80		35		73
Income (loss) per weighted average common share — basic and diluted	$	0.41	$	0.41	$	(0.22)	$	(0.22)

^(a) Basic and diluted earnings (losses) per share might not recalculate due to presenting values in millions rather than whole dollars.

	Six months ended June 30,
	2020				2019
(In millions, except per share data) (a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$	6	$	13	$	(14)	$	(30)
Weighted average number of common shares outstanding — basic and diluted	35		79		35		73
Income (loss) per weighted average common share — basic and diluted	$	0.16	$	0.16	$	(0.41)	$	(0.41)

^(a) Basic and diluted earnings (losses) per share might not recalculate due to presenting values in millions rather than whole dollars.

The following table summarizes the Company's outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted earnings per share, the 2020 Convertible Notes were repaid on June 1, 2020:

	Three months ended June 30,		Six months ended June 30,
		2019		2019
	(In millions of shares)
2020 Convertible Notes - Common Class C		2		2

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Note 9 — Changes in Capital Structure

At-the-Market Equity Offering Program, or the ATM Program

Clearway Energy, Inc. is party to an equity distribution agreement with Barclays Capital Inc., Credit Suisse Securities (USA) LLC, J.P. Morgan Securities LLC and RBC Capital Markets, LLC, as sales agents. Pursuant to the terms of the equity distribution agreement, Clearway Energy, Inc. was able to offer and sell shares of its Class C common stock from time to time through the sales agents up to an aggregate sales price of $150 million through an at-the-market equity offering program, or the ATM Program. As of June 30, 2020, the Company had completed the issuance of shares of Class C common stock available under the ATM Program.

During the six months ended June 30, 2020, Clearway Energy, Inc. issued and sold 1,749,665 shares of Class C common stock for net proceeds of $38 million. The Company utilized the proceeds of the sales to acquire 1,749,665 Class C units of Clearway Energy LLC and, as a result, the Company currently owns 57.41% of the economic interests of Clearway Energy LLC, with CEG retaining 42.59% of the economic interests of Clearway Energy LLC.

Dividends to Class A and Class C common stockholders

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.

On July 30, 2020, the Company declared quarterly dividends on its Class A common stock and Class C common stock of $0.3125 per share payable on September 15, 2020, to stockholders of record as of September 1, 2020.

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

Note 10 — Segment Reporting

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

33

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	107	$	180	$	42	$	—	$	329
Cost of operations	22		39		26		—		87
Depreciation, amortization and accretion	33		59		7		—		99
General and administrative	—		1		2		9		12
Development costs	—		—		1		—		1
Operating income (loss)	52		81		6		(9)		130
Equity in earnings of unconsolidated affiliates	1		15		—		—		16
Gain on sale of unconsolidated affiliate	—		—		—		49		49
Interest expense	(22)		(42)		(5)		(24)		(93)
Income before income taxes	31		54		1		16		102
Income tax expense	—		—		—		26		26
Net Income (Loss)	$	31	$	54	$	1	$	(10)	$	76
Total Assets	$	2,674	$	6,290	$	613	$	159	$	9,736

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	84	$	153	$	47	$	—	$	284
Cost of operations	13		35		30		—		78
Depreciation, amortization and accretion	25		58		7		—		90
Impairment losses	—		—		19		—		19
General and administrative	—		—		—		7		7
Acquisition-related transaction and integration costs	—		—		—		1		1
Development costs	—		—		2		—		2
Operating income (loss)	46		60		(11)		(8)		87
Equity in earnings of unconsolidated affiliates	2		9		—		—		11
Other income, net	—		1		—		—		1
Loss on debt extinguishment	—		(1)		—		—		(1)
Interest expense	(16)		(89)		(4)		(21)		(130)
Income (loss) before income taxes	32		(20)		(15)		(29)		(32)
Income tax expense	—		—		—		4		4
Net Income (Loss)	$	32	$	(20)	$	(15)	$	(33)	$	(36)

34

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	210	$	287	$	90	$	—	$	587
Cost of operations	46		75		59		—		180
Depreciation, amortization and accretion	66		121		14		—		201
General and administrative	—		1		3		17		21
Acquisition-related transaction and integration costs	—		—		—		1		1
Development costs	—		—		2		—		2
Operating income (loss)	98		90		12		(18)		182
Equity in earnings (losses) of unconsolidated affiliates	3		—		—		—		3
Gain on sale of unconsolidated affiliate	—		—		—		49		49
Other income, net	—		1		1		—		2
Loss on debt extinguishment	—		—		—		(3)		(3)
Interest expense	(52)		(151)		(10)		(47)		(260)
Income (loss) before income taxes	49		(60)		3		(19)		(27)
Income tax expense	—		—		—		4		4
Net Income (Loss)	$	49	$	(60)	$	3	$	(23)	$	(31)

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	163	$	241	$	97	$	—	$	501
Cost of operations	30		67		63		—		160
Depreciation, amortization and accretion	50		113		13		—		176
Impairment losses	—		—		19		—		19
General and administrative	—		—		1		12		13
Acquisition-related transaction and integration costs	—		—		—		2		2
Development costs	—		—		3		—		3
Operating income (loss)	83		61		(2)		(14)		128
Equity in earnings of unconsolidated affiliates	4		10		—		—		14
Other income, net	1		2		—		1		4
Loss on debt extinguishment	—		(1)		—		—		(1)
Interest expense	(32)		(148)		(8)		(43)		(231)
Income (loss) before income taxes	56		(76)		(10)		(56)		(86)
Income tax benefit	—		—		—		(3)		(3)
Net Income (Loss)	$	56	$	(76)	$	(10)	$	(53)	$	(83)

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Note 11 — Income Taxes

Effective Tax Rate

The income tax provision consisted of the following:

	Three months ended June 30,						Six months ended June 30,
	2020			2019			2020			2019
	(In millions, except percentages)
Income (loss) before income tax benefit	$	102		$	(32)		$	(27)		$	(86)
Income tax expense (benefit)	26			4			4			(3)
Effective income tax rate	25.5		%	(12.5)		%	(14.8)		%	3.5		%

For the three and six months ended June 30, 2020 and 2019 the overall effective tax rate was different than the statutory rate of 21% primarily due to taxable earnings and losses allocated to partners' interest in Clearway Energy LLC, which includes the effects of applying HLBV method of accounting for book purposes for certain partnerships.

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

On March 27, 2020 the Coronavirus Aid, Relief, and Economic Security (CARES) Act, or the Act, was signed into law, which includes modifications to the business interest expense disallowance and net operating loss provisions. While the Company expects to utilize previously disallowed interest expense during 2020 as a result of the modifications, the Company does not expect the Act to have a material impact on the consolidated financial statements. The Company will continue to assess the effects of the Act and ongoing government guidance related to COVID-19 that may be issued.

Note 12 — Related Party Transactions

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

O&M Services Agreements by and between the Company and Clearway Renewable Operation & Maintenance LLC

Various wholly-owned subsidiaries of the Company in the Renewables segment are party to services agreements with Clearway Renewable Operation & Maintenance LLC, or RENOM, a wholly-owned subsidiary of CEG, which provides operation and maintenance, or O&M, to these subsidiaries. The Company incurred total expenses for these services of $9 million and $18 million for each of the three and six months ended June 30, 2020, respectively. The Company incurred total expenses for these services of $7 million and $14 million for each of the three and six months ended June 30, 2019, respectively. There was a balance of $9 million and $7 million due to RENOM as of June 30, 2020 and December 31, 2019, respectively.

Administrative Services Agreements by and between the Company and CEG

Various wholly-owned subsidiaries of the Company are parties to administrative services agreements with Clearway Asset Services and Clearway Solar Asset Management, two wholly-owned subsidiaries of CEG, which provide various administrative services to the Company's subsidiaries. The Company incurred expenses under these agreements of $2 million and $4 million for each of the three and six months ended June 30, 2020, respectively. The Company incurred expenses under these agreements of $1 million and $3 million for each of the three and six months ended June 30, 2019, respectively.

CEG Master Services Agreements

The Company is a party to Master Services Agreements with CEG, or MSAs, pursuant to which CEG and certain of its affiliates or third party service providers provide certain services to the Company, including operational and administrative services, which include human resources, information systems, external affairs, accounting, procurement and risk management services, and the Company provides certain services to CEG, including accounting, internal audit, tax and treasury services, in exchange for the payment of fees in respect of such services. Amounts due to CEG or its subsidiaries related to these MSAs are recorded as accounts payable - affiliate and amounts due to the Company from CEG and subsidiaries are recorded as accounts receivable - affiliate on the Company's consolidated balance sheet. The Company incurred expenses of $0.6 million and

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$1.2 million under these agreements for each of the three and six months ended June 30, 2020, respectively. The expenses under these agreements were immaterial to the Company's financials for each of the three and six months ended June 30, 2019.

Note 13 — Contingencies

This note should be read in conjunction with the complete description under Note 17, Commitments and Contingencies, to the Company's 2019 Form 10-K.

Contingencies

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

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

Nebraska Public Power District Litigation

On January 11, 2019, Nebraska Public Power District, or NPPD, sent written notice to certain of the Company’s subsidiaries which own the Laredo Ridge and Elkhorn Ridge wind projects alleging an event of default under each of the PPAs between NPPD and the projects. NPPD alleges that the Company moved forward with certain transactions without obtaining the consent of NPPD. NPPD threatened to terminate the applicable PPAs by February 11, 2019 if the alleged default was not cured. The Company filed a motion for a temporary restraining order and preliminary injunction in the U.S. District Court for the District of Nebraska relating to the Laredo Ridge project, and a similar motion in the District Court of Knox County, Nebraska for the Elkhorn Ridge project, to enjoin NPPD from taking any actions related to the PPAs. On February 19, 2019, the U.S. District Court in the Laredo Ridge matter approved a stipulation between the parties to provide for an injunction preventing NPPD from terminating the PPA pending disposition of the litigation. On February 26, 2019, the Knox County District Court approved a similar stipulation relating to the Elkhorn Ridge project. On April 13, 2020, the U.S. District Court granted the wind projects' motion for summary judgment and permanently enjoined NPPD from terminating the PPAs in reliance on the alleged events of default. The U.S. District Court decision was appealed by NPPD on May 11, 2020 and the case in the Knox County District Court remains pending, but has been stayed pending the outcome of the U.S. District Court case. The Company believes the allegations of NPPD are meritless and the Company is vigorously defending its rights under the PPAs.

Buckthorn Solar Litigation

On October 8, 2019, the City of Georgetown, Texas, or Georgetown, filed a petition in the District Court of Williamson County, Texas naming Buckthorn Westex, LLC, the Company’s subsidiary that owns the Buckthorn Westex solar project, as the defendant, alleging fraud by nondisclosure and breach of contract in connection with the project and the PPA, and seeking (i) rescission and/or cancellation of the PPA, (ii) declaratory judgment that the alleged breaches constitute an event of default under the PPA entitling Georgetown to terminate, and (iii) recovery of all damages, costs of court, and attorneys’ fees. On November 15, 2019, Buckthorn Westex filed an original answer and counterclaims (i) denying Georgetown’s claims, (ii) alleging Georgetown has breached its contracts with Buckthorn Westex by failing to pay amounts due, and (iii) seeking relief in the form of (x) declaratory judgment that Georgetown’s alleged failure to pay amounts due constitute breaches of and an event of default under the PPA and that Buckthorn did not commit any events of default under the PPA, (y) recovery of costs, expenses, interest, and attorneys’ fees, and (z) such other relief to which it is entitled at law or in equity. Buckthorn Westex believes the allegations of Georgetown are meritless, and Buckthorn Westex is vigorously defending its rights under the PPA.

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Note 14 — Leases

Accounting for Leases

The Company evaluates each arrangement at inception to determine if it contains a lease. All of the Company’s leases are operating leases as of June 30, 2020.

Lessee

The Company records its operating lease liabilities at the present value at lease commencement date of the lease payments over the lease term. Lease payments include fixed payment amounts, as well as variable rate payments based on an index initially measured at lease commencement date. Variable payments, including payments based on future performance and based on index changes, are recorded as the expense is incurred. The Company determines the relevant lease term by evaluating whether renewal and termination options are reasonably to certain to be exercised. The Company uses its incremental borrowing rate to calculate the present value of the lease payments, based on information available at the lease commencement date.

The Company’s leases consist of land leases for numerous operating asset locations, real estate leases and equipment leases. The terms and conditions for these leases vary by the type of underlying asset.

Lease expense was comprised of the following:

	Three months ended June 30, 2020		Three months ended June 30, 2019		Six months ended June 30, 2020		Six months ended June 30, 2019
	(In millions)
Operating lease cost - Fixed	$	5	$	2	$	9	$	4
Operating lease cost - Variable	3		3		5		7
Total lease cost	$	8	$	5	$	14	$	11

The Company lease liabilities as of June 30, 2020 and December 31, 2019 comprised of the following:

	June 30, 2020			December 31, 2019
	(In millions, except term and rate)
ROU Assets - operating leases, net	$	257		$	223
Short-term lease liability - operating leases (a)	7			7
Long-term lease liability - operating leases	260			227
Total lease liability	$	267		$	234
Weighted average remaining lease term	24			25
Weighted average discount rate	4.3		%	4.4		%
	Six months ended June 30, 2020			Six months ended June 30, 2019
Cash paid for operating leases	$	10		$	7

^(a) Short-term lease liability balances are included within the accrued expenses and other current liabilities line item of the consolidated balance sheets as of June 30, 2020 and December 31, 2019.

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Maturities of operating lease liabilities as of June 30, 2020 are as follows:

(In millions)
Remainder of 2020	$	8
2021	18
2022	18
2023	18
2024	18
Thereafter	359
Total lease payments	439
Less imputed interest	(172)
Total lease liability - operating leases	$	267

Oahu Solar Lease Agreements

The Oahu Solar projects are party to various land lease agreements with a wholly owned subsidiary of CEG. The projects are leasing the land for a period of 35 years, with the ability to renew the lease for two additional five year periods. The Company has a lease liability of $20 million and $21 million as of December 31, 2019 and a corresponding right-of-use asset of $18 million and $19 million related to leases as of June 30, 2020 and December 31, 2019, respectively.

Lessor

        The majority of the Company’s revenue is obtained through PPAs or other contractual agreements that are accounted for as leases. These leases are comprised of both fixed payments and variable payments contingent upon volumes or performance metrics. The terms of the leases are further described in Item 2 — MD&A, Introduction, Environmental, Regulatory of this Form 10-Q. Many of the leases have renewal options at the end of the lease term. Termination may be allowed under specific circumstances in the lease arrangements, such as under an event of default. All of the Company’s leases are operating leases. Certain of these leases have both lease and non-lease components, and the Company allocates the transaction price to the components based on standalone selling prices. As disclosed in Note 2, Summary of Significant Accounting Policies, the following amounts of energy and capacity revenue are related to the Company’s leases:

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	181	$	—	$	182
Capacity revenue	112		—		—		112
Operating revenue	$	113	$	181	$	—	$	294

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	3	$	296	$	1	$	300
Capacity revenue	219		—		—		219
Operating revenue	$	222	$	296	$	1	$	519

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	157	$	1	$	159
Capacity revenue	85		—		—		85
Operating revenue	$	86	$	157	$	1	$	244

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	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	2	$	256	$	1	$	259
Capacity revenue	164		—		—		164
Operating revenue	$	166	$	256	$	1	$	423

Minimum future rent payments under the operating leases for the remaining periods as of June 30, 2020

(In millions)
Remainder of 2020	$	297
2021	444
2022	450
2023	259
2024	106
Thereafter	1,605
Total lease payments	$	3,161

Property, plant and equipment, net related to the Company’s operating leases were as follows:

(In millions)	June 30, 2020		December 31, 2019
Property, plant and equipment	$	6,974	$	6,942
Accumulated depreciation	(1,769)		(1,649)
Net property, plant and equipment	$	5,205	$	5,293

Note 15 — Asset Impairments

During the three and six months and ended June 30, 2019, the Company recorded an impairment loss of $19 million related to a facility in the Thermal segment. The fair value of the facility was determined using an income approach by applying a discounted cash flow methodology to the long-term budgets for each respective plant. The income approach utilized estimates of discounted future cash flows, which were Level 3 fair value measurement and include key inputs, such as forecasted power prices, operations and maintenance expense, and discount rates. The Company measured the impairment loss as the difference between the carrying amount and the fair value of the assets.

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

The following discussion analyzes the Company's historical financial condition and results of operations.

As you read this discussion and analysis, refer to the Company's Consolidated Financial Statements to this Form 10-Q, which present the results of operations for the three and six months ended June 30, 2020 and 2019. Also refer to the Company's 2019 Form 10-K, which includes detailed discussions of various items impacting the Company's business, results of operations and financial condition.

The discussion and analysis below has been organized as follows:

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

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

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

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

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

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Executive Summary

Introduction and Overview

Clearway Energy, Inc. together with its consolidated subsidiaries, or the Company, is a publicly-traded energy infrastructure investor in and owner of modern, sustainable and long-term contracted assets across North America. The Company is indirectly owned by Global Infrastructure Partners III. Global Infrastructure Management, LLC is an independent fund manager of funds that invests in infrastructure assets in the energy and transport sectors, and Global Infrastructure Partners III is its third equity fund. The Company is sponsored by GIP through GIP's portfolio company, CEG.

The Company’s environmentally-sound asset portfolio includes over 5,991 MW of wind, solar and natural gas-fired power generation facilities, as well as district energy systems. Through this diversified and contracted portfolio, the Company endeavors to provide its investors with stable and growing dividend income. Substantially all of the Company's generation assets are under long-term contractual arrangements for the output or capacity from these assets. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,453 net MWt and electric generation capacity of 36 net MW. These thermal infrastructure assets provide steam, hot and/or chilled water, and, in some instances, electricity to commercial businesses, universities, hospitals and governmental units in multiple locations, principally through long-term contracts or pursuant to rates regulated by state utility commissions. The weighted average remaining contract duration of these offtake agreements was approximately 13 years as of June 30, 2020 based on CAFD.

As of June 30, 2020, the Company's operating assets are comprised of the following projects:

Projects	Percentage Ownership		Net Capacity (MW)(a)	Offtake Counterparty	Expiration
Conventional
Carlsbad	100	%	527	San Diego Gas & Electric	2038
El Segundo	100	%	550	Southern California Edison	2023
GenConn Devon	50	%	95	Connecticut Light & Power	2040
GenConn Middletown	50	%	95	Connecticut Light & Power	2041
Marsh Landing	100	%	720	Pacific Gas and Electric	2023
Walnut Creek	100	%	485	Southern California Edison	2023
			2,472
Utility Scale Solar
Agua Caliente	16	%	46	Pacific Gas and Electric	2039
Alpine	100	%	66	Pacific Gas and Electric	2033
Avenal	50	%	23	Pacific Gas and Electric	2031
Avra Valley	100	%	26	Tucson Electric Power	2032
Blythe	100	%	21	Southern California Edison	2029
Borrego	100	%	26	San Diego Gas and Electric	2038
Buckthorn Solar (b)	100	%	154	City of Georgetown, TX	2043
CVSR	100	%	250	Pacific Gas and Electric	2038
Desert Sunlight 250	25	%	63	Southern California Edison	2034
Desert Sunlight 300	25	%	75	Pacific Gas and Electric	2039
Kansas South	100	%	20	Pacific Gas and Electric	2033
Kawailoa (b)	48	%	24	Hawaiian Electric Company	2041
Oahu Solar Projects (b)	95	%	58	Hawaiian Electric Company	2041
Roadrunner	100	%	20	El Paso Electric	2031
TA High Desert	100	%	20	Southern California Edison	2033
Utah Solar Portfolio (b) (e)	50	%	265	PacifiCorp	2036
			1,157
Distributed Solar
Apple I LLC Projects	100	%	3	Various	2032
AZ DG Solar Projects	100	%	5	Various	2025 - 2033
Clearway Chestnut Projects(b)	99	%	59	Various	2032-2034
Renew Solar CS4 Projects(b)	99	%	54	Various	2029-2044
SPP Projects	100	%	25	Various	2026 - 2037
Other DG Projects	100	%	13	Various	2023 - 2039
			159

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Projects	Percentage Ownership		Net Capacity (MW)(a)	Offtake Counterparty	Expiration
Wind
Alta I	100	%	150	Southern California Edison	2035
Alta II	100	%	150	Southern California Edison	2035
Alta III	100	%	150	Southern California Edison	2035
Alta IV	100	%	102	Southern California Edison	2035
Alta V	100	%	168	Southern California Edison	2035
Alta X (b)	100	%	137	Southern California Edison	2038
Alta XI (b)	100	%	90	Southern California Edison	2038
Buffalo Bear	100	%	19	Western Farmers Electric Co-operative	2033
Crosswinds	99	%	21	Corn Belt Power Cooperative	2027
Elbow Creek (b)	100	%	122	Various	2029
Elkhorn Ridge	66.7	%	54	Nebraska Public Power District	2029
Forward	100	%	29	Constellation NewEnergy, Inc.	2022
Goat Wind	100	%	150	Dow Pipeline Company	2025
Hardin	99	%	15	Interstate Power and Light Company	2027
Laredo Ridge	100	%	80	Nebraska Public Power District	2031
Lookout	100	%	38	Southern Maryland Electric Cooperative	2030
Odin	99.9	%	20	Missouri River Energy Services	2028
Pinnacle	100	%	55	Maryland Department of General Services and University System of Maryland	2031
San Juan Mesa	75	%	90	Southwestern Public Service Company	2025
Sleeping Bear	100	%	95	Public Service Company of Oklahoma	2032
South Trent	100	%	101	AEP Energy Partners	2029
Spanish Fork	100	%	19	PacifiCorp	2028
Spring Canyon II (b)	90.1	%	31	Platte River Power Authority	2039
Spring Canyon III (b)	90.1	%	26	Platte River Power Authority	2039
Taloga	100	%	130	Oklahoma Gas & Electric	2031
Wildorado (b)	100	%	161	Southwestern Public Service Company	2027
			2,203
Thermal
Thermal Generation .	100	%	36	Various	Various
Total net generation capacity (c)			6,027
Thermal equivalent MWt(d)	92.9	%	1,453	Various	Various

^(a) Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of June 30, 2020.

^(b) Projects are part of tax equity arrangements, as further described in Item 1 — Note 2, Summary of Significant Accounting Policies.

^(c) Clearway Energy, Inc.'s total generation capacity is net of 6 MWs for noncontrolling interest for Spring Canyon II and III. Clearway Energy, Inc.'s generation capacity including this noncontrolling interest was 6,033 MWs.

^(d) For thermal energy, net capacity represents MWt for steam or chilled water and excludes 19 MWt available under the right-to-use provisions contained in agreements between one of the Company's thermal facilities and certain of its customers.

^(e) Represents interests in Four Brothers Solar, LLC, Granite Mountain Holdings, LLC, and Iron Springs Holdings, LLC, all acquired as part

of the March 2017 Drop Down Assets (ownership percentage is based upon cash to be distributed).

Additionally, the Company is party to partnerships the purpose of which is to own or purchase solar power generation projects, as well as other ancillary related assets from a related party via intermediate funds.  The Company does not consolidate these partnerships and accounts for them as equity method investments. The Company's net interest in these projects is 165 MW based on cash to be distributed pursuant to the partnership agreements as of June 30, 2020. For further discussions, see Item 1— Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities of this Form 10-Q and Item 15 — Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities to the consolidated financial statements included in the Company's 2019 Form 10-K.

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Significant Events

Pacific Gas and Electric Company Bankruptcy Update

•During 2019, PG&E, one of the Company's largest customers, filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the Northern District of California, or the Bankruptcy Court. The PG&E Bankruptcy triggered defaults under the PPAs with PG&E and such related financing agreements. As a result, the Company had previously recorded approximately $1.19 billion of principal, net of the related unamortized debt issuance costs, as short-term debt. On July 1, 2020, PG&E emerged from bankruptcy and assumed the Company's contracts without modification. In addition, PG&E paid to the Company's applicable projects the portion of the invoices corresponding to the electricity delivered between January 1 and January 28, 2019. These invoices related to the pre-petition period services and any payment therefore required the approval of the Bankruptcy Court. The Company has reclassified the related debt to non-current based on its original maturity as of June 30, 2020.

Financing Activities

•On May 21, 2020, Clearway Energy Operating LLC completed the sale of an additional $250 million aggregate principal amount of the 2028 Senior Notes. The 2028 Senior Notes bear interest at 4.75% and mature on March 15, 2028. Interest on the 2028 Senior Notes is payable semi-annually on March 15 and September 15 of each year, and interest payments will commence on September 15, 2020. The 2028 Senior Notes are unsecured obligations of Clearway Energy Operating LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC's wholly owned current and future subsidiaries. The proceeds from the additional 2028 Senior Notes were used to repay the $45 million outstanding principal amount of the Company's 2020 Convertible Notes on June 1, 2020, as well as to fund the repayment of outstanding borrowings under the Company's revolving credit facility and for general corporate purposes.

Drop Down Transactions

•On August 3, 2020, the Company entered into an agreement with CEG to acquire an interest in Mesquite Star Pledgor LLC, which owns the Mesquite Star wind project, a 419 MW utility scale wind project located in Fisher County, Texas for approximately $79 million. The acquisition is expected to close during the third quarter of 2020 and will be funded with existing liquidity.

•On August 3, 2020, CEG offered the Company the opportunity to purchase (i) residual interests in the Kawailoa and Oahu Solar Partnerships and (ii) 100% of its interests in Langford Holding, LLC, which owns the Langford wind project. The transaction is subject to negotiation and approval by the Company's Independent Directors.

•On April 17, 2020, the Company entered into binding agreements related to the previously announced drop-down offer from CEG to enable the Company to acquire and invest in a portfolio of renewable energy projects. The following projects are included in the drop-down: (i) 100% of the equity interests in Rattlesnake Flat, LLC, which owns the Rattlesnake Wind Project, a 144 net MW wind facility located in Adams County, WA; (ii) CEG's interest in Repowering Partnership II LLC (Repowering 1.0), which the Company acquired on May 11, 2020; and (iii) a new partnership with CEG to repower the Pinnacle Wind Project, a 55 net MW wind facility located in Mineral County, WV. The Company expects to invest approximately $241 million in corporate capital subject to closing adjustments for the above mentioned transactions. Closing is subject to the timing of projects achieving commercial operations. The investment at commercial operations excludes, subject to closing adjustments, an additional $27 million payment in 2031 at the Pinnacle Wind Repowering Partnership.

•On May 11, 2020, the Company acquired CEG's interest in Repowering Partnership II LLC for cash consideration of $70 million. Repowering Partnership II LLC is no longer a VIE and subsequent to the acquisition, is a wholly-owned subsidiary of the Company.

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Sale of Interest in RPV Holdco 1

•On May 14, 2020, the Company sold its interests in RPV Holdco 1 LLC, or RPV Holdco, to a third party for net proceeds of approximately $75 million. The Company previously accounted for its interest in RPV Holdco as an equity method investment. The sale of the investment resulted in a gain of approximately $49 million.

Consolidation of DGPV Holdco 3

•On May 29, 2020, the final construction projects owned by DGPV Holdco 3 were placed in service which resulted in a reconsideration event. The Company determined that it will consolidate DGPV Holdco 3 effective on May 29, 2020 and show the interest owned by CEG as noncontrolling interest as of that date. This resulted in the consolidation of assets of $400 million and liabilities of $290 million as of May 29, 2020. The impact to the results of operations for the period from May 30, 2020 to June 30, 2020 was not material.

Black Start Services at Marsh Landing

•As of July 2020, all necessary regulatory approvals were obtained with respect to the Company's Marsh Landing project to provide black start capability in the greater San Francisco Bay area, which would restart Marsh Landing in the event of a blackout, under a five-year contract with the California Independent System Operator to support their emergency restoration of the electrical grid. The project has commenced construction and is expected to achieve commercial operations in 2021.

Environmental Matters

The Company is subject to a wide range of environmental laws during the development, construction, ownership and operation of facilities. These existing and future laws generally require that governmental permits and approvals be obtained before construction and maintained during operation of facilities. The Company is obligated to comply with all environmental laws and regulations applicable within each jurisdiction and required to implement environmental programs and procedures to monitor and control risks associated with the construction, operation and decommissioning of regulated or permitted energy assets. Federal and state environmental laws have historically become more stringent over time, although this trend could change in the future.

A number of regulations that may affect the Company are under review, including the publishing of the Affordable Clean Energy (ACE) rule, state solar photovoltaic module (solar panel) disposal and recycling regulations, and proposed federal MBTA incidental take legislation and regulations. The Company will evaluate the impact of the legislation and regulations as they are revised but cannot fully predict the impact of each until anticipated revisions and legal challenges are resolved. To the extent the proposed legislation and regulations restrict or otherwise impact the Company's operations, the proposed legislation and regulations could have a negative impact on the Company's financial performance.

Affordable Clean Energy Rule — The attention in recent years on GHG emissions has resulted in federal regulations and state legislative and regulatory action. In 2015, the EPA finalized the Clean Power Plan, or the CPP, which addressed GHG emissions from existing electric utility steam generating units. The CPP was challenged in court and in 2016 the U.S. Supreme Court stayed the CPP. In 2018, the EPA published the proposed ACE rule to replace the CPP. The ACE rule establishes emission guidelines for states to develop plans to address greenhouse gas emissions from existing power plants. The ACE rule also reinforces the states’ broad discretion in establishing and applying emissions standards to new emission sources. The ACE rule is currently being litigated in the D.C. Circuit.

Proposed State Solar Photovoltaic Module Disposal and Recycling Regulations — On October 1, 2015, California enacted SB 489, which authorized California’s Department of Toxic Substances Control to adopt regulations to designate discarded photovoltaic modules, which are classified as hazardous waste, as universal waste subject to universal waste management. On April 19, 2019, the department proposed regulations that would allow discarded photovoltaic modules to be managed as universal waste. Comments on the proposed rule were due by June 10, 2019, but the date was extended to January 8, 2020, as a result of text modifications. The final rule has not yet been published.

Proposed Federal MBTA Incidental Take Legislation and Regulations — On January 15, 2020, the House Natural Resources Committee voted to advance a bill that would reinstate the interpretation that incidental take is prohibited under the MBTA, overriding the recent Trump-administration Solicitor’s Opinion M-37050 that held the MBTA only applies to intentional takings. The bill also develops a general permitting program that covers incidental take of migratory birds. To the extent that electric generation takes migratory birds, it typically is incidental to its operations.

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On February 3, 2020, the U.S. Fish and Wildlife Service published in the Federal Register a notice of proposed rulemaking to solicit public comment on a proposed regulation that would codify Solicitor’s Opinion M-37050 defining the scope of certain prohibitions under the MBTA. The proposed rule would clarify that criminal liability for pursuing, hunting, taking, capturing, or killing or attempting to take, capture or kill migratory birds is limited to actions directed at migratory birds, their nests, or their eggs. The proposed rule would have the effect of clarifying that these prohibitions do not extend to actions that only incidentally take or kill migratory birds as a result of otherwise lawful activities. Comments on the proposed rule were due by March 19, 2020. The final rule has not yet been published. On June 5, 2020, the US Fish and Wildlife Service made available the draft Environmental Impact Statement (DEIS) for the proposed rule to define the scope of the MBTA. A 45-day comment period on the DEIS was opened.

Regulatory Matters

The Company’s regulatory matters are described in the Company’s 2019 Form 10-K in Item 1, Business — Regulatory Matters and Item 1A, Risk Factors.

Trends Affecting Results of Operations and Future Business Performance

The Company’s trends are described in the Company’s 2019 Form 10-K in Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations — Trends Affecting Results of Operations and Future Business Performance.

Recent Developments Affecting Industry Conditions and the Company’s Business

In response to the ongoing coronavirus (COVID-19) pandemic, the Company has implemented preventative measures and developed corporate and regional response plans to protect the health and safety of its employees, customers and other business counterparties, while supporting the Company’s suppliers and customers’ operations to the best of its ability in the circumstances. The Company also has modified certain business practices (including discontinuing all non-essential business travel, implementing a temporary work-from-home policy for employees who can execute their work remotely and encouraging employees to adhere to local and regional social distancing, more stringent hygiene and cleaning protocols across the Company’s facilities and operations and self-quarantining recommendations) to support efforts to reduce the spread of COVID-19 and to conform to government restrictions and best practices encouraged by governmental and regulatory authorities. The Company continues to evaluate these measures, response plans and business practices in light of the evolving effects of COVID-19.

There is considerable uncertainty regarding the extent to which COVID-19 will continue to spread and the extent and duration of governmental and other measures implemented to try to slow the spread of the virus, such as large-scale travel bans and restrictions, border closures, quarantines, shelter-in-place orders and business and government shutdowns. Restrictions of this nature may cause the Company, its suppliers and other business counterparties to experience operational delays and delays in the delivery of materials and supplies and may cause milestones or deadlines relating to various projects to be missed.

As of the date of this report, the Company has not experienced any material financial or operational impacts related to COVID-19. All of the Company’s facilities have remained operational. The Company believes that all of its accounts receivable balances as of June 30, 2020 are collectible. The Company will continue to assess collectability based on any future developments.

The Company cannot predict the full impact that COVID-19 will have on the Company’s financial expectations, its financial condition, results of operations and cash flows, its ability to make distributions to its stockholders, the market prices of its common stock and its ability to satisfy its debt service obligations at this time, due to numerous uncertainties. The ultimate impacts will depend on future developments, including, among others, the ultimate geographic spread of the virus, the consequences of governmental and other measures designed to prevent the spread of the virus, the development of effective treatments, the duration of the outbreak, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability and the timing and extent to which normal economic and operating conditions resume. For additional discussion regarding risks associated with the COVID-19 pandemic, see Part II, Item 1A Risk Factors of the Company's Quarterly Report on Form 10-Q for the fiscal quarter ended March 31, 2020.

46

Consolidated Results of Operations

The following table provides selected financial information:

	Three months ended June 30,						Six months ended June 30,
(In millions)	2020		2019		Change		2020		2019		Change
Operating Revenues
Energy and capacity revenues	$	342	$	292	$	50	$	618	$	525	$	93
Other revenues	12		9		3		21		17		4
Contract amortization	(22)		(17)		(5)		(44)		(34)		(10)
Mark-to-market economic hedging activities	(3)		—		(3)		(8)		(7)		(1)
Total operating revenues	329		284		45		587		501		86
Operating Costs and Expenses
Cost of fuels	13		15		(2)		30		34		(4)
Operations and maintenance	54		44		10		110		89		21
Other costs of operations	20		19		1		40		37		3
Depreciation, amortization and accretion	99		90		9		201		176		25
Impairment losses	—		19		(19)		—		19		(19)
General and administrative	12		7		5		21		13		8
Transaction and integration costs	—		1		(1)		1		2		(1)
Development costs	1		2		(1)		2		3		(1)
Total operating costs and expenses	199		197		2		405		373		32
Operating Income	130		87		43		182		128		54
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	16		11		5		3		14		(11)
Gain on sale of unconsolidated affiliate	49		—		49		49		—		49
Other income, net	—		1		(1)		2		4		(2)
Loss on debt extinguishment	—		(1)		1		(3)		(1)		(2)
Interest expense	(93)		(130)		37		(260)		(231)		(29)
Total other expense, net	(28)		(119)		91		(209)		(214)		5
Income (Loss) Before Income Taxes	102		(32)		134		(27)		(86)		59
Income tax expense (benefit)	26		4		22		4		(3)		7
Net Income (Loss)	76		(36)		112		(31)		(83)		52
Less: Income (loss) attributable to noncontrolling interests and redeemable interests	29		(12)		41		(49)		(39)		(10)
Net Income (Loss) Attributable to Clearway Energy, Inc.	$	47	$	(24)	$	71	$	18	$	(44)	$	62

	Three months ended June 30,				Six months ended June 30,
Business metrics:	2020		2019		2020		2019
Renewables MWh generated/sold (in thousands) (a)	2,259		1,948		3,934		3,397
Thermal MWt sold (in thousands)	395		453		1,000		1,112
Thermal MWh sold (in thousands)	11		45		38		59
Conventional MWh generated (in thousands) (a) (b)	204		214		381		325
Conventional equivalent availability factor	95.1	%	92.1	%	92.0	%	87.5	%

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

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

47

Management’s Discussion of the Results of Operations for the Three Months Ended June 30, 2020 and 2019

Gross Margin

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

Economic Gross Margin

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

The below tables present the composition of gross margin, as well as the reconciliation to economic gross margin, for the three months ended June 30, 2020 and 2019:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Three months ended June 30, 2020
Energy and capacity revenues	$	113	$	195	$	34	$	342
Other revenues	—		4		8		12
Cost of fuels	(1)		—		(12)		(13)
Contract amortization	(6)		(16)		—		(22)
Mark-to-market economic hedging activities	—		(3)		—		(3)
Gross margin	106		180		30		316
Contract amortization	6		16		—		22
Mark-to-market economic hedging activities	—		3		—		3
Economic gross margin	$	112	$	199	$	30	$	341
Three months ended June 30, 2019
Energy and capacity revenues	$	86	$	166	$	40	$	292
Other revenues	—		2		7		9
Cost of fuels	—		—		(15)		(15)
Contract amortization	(2)		(15)		—		(17)
Gross margin	84		153		32		269
Contract amortization	2		15		—		17
Economic gross margin	$	86	$	168	$	32	$	286

Gross margin increased by $47 million during the three months ended June 30, 2020, compared to the same period in 2019, due to a combination of the drivers summarized in the table below:

Segment		(In millions)
Renewables	Increase primarily due to a $9 million increase due to the prior year outage at CVSR in June 2019, an increase of $7 million related to the Oahu and Kawailoa facilities achieving COD in late 2019, a $4 million increase due to the completion of the repowering of Elbow Creek and Wildorado and an increase of $3 million from the consolidation of the Chestnut and CS4 Funds in May 2020	$	27
Conventional	Increase is due primarily to the acquisition of Carlsbad Energy in December 2019	22
Thermal	Decrease primarily due to the sale of Dover on March 2, 2020	(2)
		$	47

48

Operations and Maintenance Expense

Operations and maintenance expense increased by $10 million during the three months ended June 30, 2020, compared to the same period in 2019, due to a $7 million increase in the Conventional segment related to the acquisition of the Carlsbad Energy Center in December 2019 and a $3 million increase in the Renewables segment due to increased operations and maintenance expense related to the projects achieving COD in late 2019 and early 2020, including the Oahu and Kawailoa facilities and Elbow Creek and Wildorado repowering.

Depreciation, Amortization and Accretion Expense

Depreciation, amortization and accretion expense increased by $9 million during the three months ended June 30, 2020, compared to the same period in 2019, primarily due to an $8 million increase in the Conventional segment related to the acquisition of the Carlsbad Energy Center in December 2019.

Impairment Losses

Impairment losses of $19 million during the three months ended June 30, 2019, relate to a facility within the Company's Thermal segment, as further described in Note 15, Asset Impairments.

General and Administrative Expense

General and administrative expense increased by $5 million during the three months ended June 30, 2020, compared to the same period in 2019, primarily due to an increase in MSA fees charged by CEG, personnel costs and consulting fees.

Equity in Earnings of Unconsolidated Affiliates

Equity in earnings of unconsolidated affiliates increased by $5 million during the three months ended June 30, 2020, compared to the same period in 2019, primarily driven by changes in the HLBV values for the Utah and DGPV investments.

Gain on Sale of Unconsolidated Affiliate

On May 14, 2020, the Company sold its interests in RPV Holdco 1 LLC, or RPV Holdco, to a third party which resulted in a gain on sale of investment of approximately $49 million. For further discussion on this transaction, see Note 3 - Acquisition and Dispositions.

Interest Expense  

Interest expense decreased by $37 million during the three months ended June 30, 2020, compared to the same period in 2019, due to the following:

	(In millions)
Change in fair value of interest rate swaps	$	(23)
Reclassification of losses previously deferred in AOCI to the statement of operations in connection with project-level debt refinancing activities	(23)
Additional interest expense for Carlsbad Energy Center which was acquired on December 5, 2019	9
	$	(37)

Income Tax Expense

For the three months ended June 30, 2020, the Company recorded an income tax expense of $26 million on a pretax income of $102 million. For the same period in 2019, the Company recorded an income tax expense of $4 million on a pretax loss of $32 million.

For the three months ended June 30, 2020 and June 30, 2019, the overall effective tax rate was different than the statutory rate of 21% primarily due to taxable earnings and losses allocated to partners' interests in Clearway Energy LLC, which includes the effects of applying HLBV method of accounting for book purposes for certain partnerships.

49

Income Attributable to Noncontrolling Interests

For the three months ended June 30, 2020, the Company had income of $56 million attributable to CEG's economic interest in Clearway Energy LLC, offset in part by losses of $15 million related to CEG's interests in the Repowering partnership through the acquisition date of May 11, 2020, as well as losses of $12 million attributable to noncontrolling interests with respect to its tax equity financing arrangements and the application of the HLBV method.

For the three months ended June 30, 2019, the Company had a loss of $14 million attributable to CEG's economic interest in Clearway Energy LLC, as well as a loss of $4 million attributable to CEG's interests in the Kawailoa, Oahu and Repowering partnerships, partially offset by income of $6 million attributable to noncontrolling interests with respect to its tax equity financing arrangements and the application of the HLBV method.

50

Management’s Discussion of the Results of Operations for the Six Months Ended June 30, 2020 and 2019

Gross Margin

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

Economic Gross Margin

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

The below tables present the composition of gross margin, as well as the reconciliation to economic gross margin, for the six months ended June 30, 2020 and 2019:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Six months ended June 30, 2020
Energy and capacity revenue	$	222	$	320	$	76	$	618
Other revenue	—		6		15		21
Cost of fuels	(2)		—		(28)		(30)
Contract amortization	(12)		(31)		(1)		(44)
Mark-to-market for economic hedges	—		(8)		—		(8)
Gross margin	208		287		62		557
Contract amortization	12		31		1		44
Mark-to-market for economic hedges	—		8		—		8
Economic gross margin	$	220	$	326	$	63	$	609
Six months ended June 30, 2019
Energy and capacity revenue	$	166	$	274	$	85	$	525
Other revenue	—		4		13		17
Cost of fuels	—		—		(34)		(34)
Contract amortization	(3)		(30)		(1)		(34)
Mark-to-market for economic hedging activities	—		(7)		—		(7)
Gross margin	163		241		63		467
Contract amortization	3		30		1		34
Mark-to-market for economic hedging activities	—		7		—		7
Economic gross margin	$	166	$	278	$	64	$	508

51

Gross margin increased by $90 million during the six months ended June 30, 2020, compared to the same period in 2019 primarily due to a combination of the following:

Segment		(In millions)
Renewables	Increase of $20 million related to higher wind energy production primarily at Alta, as well as the completion of the repowering of Elbow Creek and Wildorado. Additional increases of $9 million were due to the prior year outage at CVSR, $11 million due to the Oahu and Kawailoa facilities achieving COD in late 2019 and $3 million from the consolidation of the Chestnut and CS4 Funds in May 2020	$	46
Conventional	Increase is due primarily to the acquisition of Carlsbad Energy in December 2019	45
Thermal	Decrease of $3 million related to the sale of the Energy Center Dover on March 2, 2020, offset by an increase of $2 million related to the acquisition of the Duquesne University Energy System on May 1, 2019	(1)
		$	90

Operations and Maintenance Expense

Operations and maintenance expense increased by $21 million during the six months ended June 30, 2020, compared to the same period in 2019. This is due to a $13 million increase in the Conventional segment related to the acquisition of the Carlsbad Energy Center in December 2019 and an $8 million increase in the Renewables segment related to COD having been reached for the Oahu and Kawailoa facilities in late 2019 and the repowering of Elbow Creek and Wildorado in late 2019 and early 2020.

Depreciation, Amortization and Accretion Expense

Depreciation, amortization and accretion expense increased by $25 million during the six months ended June 30, 2020, compared to the same period in 2019 primarily due to a $16 million increase in the Conventional segment related to the acquisition of the Carlsbad Energy Center in December 2019 and a $9 million increase in the Renewables Segment due to the Oahu and Kawailoa projects which reached COD in late 2019 as well as the completion of the repowering activities at Elbow Creek and Wildorado projects in the fourth quarter of 2019 and the first quarter of 2020.

Impairment Losses

Impairment losses of $19 million during the six months ended June 30, 2019, relate to a facility within the Company's Thermal segment, as further described in Note 15, Asset Impairments.

General and Administrative Expense

General and administrative expense increased by $8 million during the six months ended June 30, 2020, compared to the same period in 2019, primarily due to an increase in MSA fees charged by CEG, personnel costs and consulting fees.

Equity in Earnings of Unconsolidated Affiliates

Equity in earnings of unconsolidated affiliate decreased by $11 million during the six months ended June 30, 2020, compared to the same period in 2019, primarily driven by changes in the HLBV values for the Utah, RPV and DGPV investments.

Gain on Sale of Unconsolidated Affiliate

On May 14, 2020, the Company sold its interests in RPV Holdco 1 LLC, or RPV Holdco, to a third party which resulted in a gain on sale of investment of approximately $49 million. For further discussion on this transaction, see Note 3 - Acquisition and Dispositions.

52

Interest Expense  

Interest expense increased by $29 million during the six months ended June 30, 2020, compared to the same period in 2019, primarily due to the following:

	(In millions)
Change in fair value of interest rate swaps	$	36
Additional interest expense for Carlsbad Energy Center which was acquired on December 5, 2019	17
Reclassification of losses previously deferred in AOCI to the statement of operations in connection with project-level debt refinancing activities	(14)
Decrease in interest expense due to lower principal balances of project level debt for the remainder of the portfolio	(13)
Increase in Corporate interest expense due to additional revolver borrowings and the issuance of the additional Senior Notes due 2028	3
	$	29

Income Tax Expense

For the six months ended June 30, 2020, the Company recorded an income tax expense of $4 million on a pretax loss of $27 million. For the same period in 2019, the Company recorded an income tax benefit of $3 million on a pretax loss of $86 million.

For the six months ended June 30, 2020 and 2019, the overall effective tax rate was different than the statutory rate of 21% primarily due to the taxable earnings and losses allocated to the partners' interest in Clearway Energy LLC, which includes the effects of applying HLBV method of accounting for book purposes for certain partnerships.

Income Attributable to Noncontrolling Interests

For the six months ended June 30, 2020, the Company had income of $17 million attributable to CEG's economic interest in Clearway Energy LLC offset by losses of $35 million attributable to CEG's interests in the Kawailoa, Oahu and Repowering partnerships and losses of $31 million attributable to noncontrolling interests with respect to its tax equity financing arrangements and the application of the HLBV method.

For the six months ended June 30, 2019, the Company had a loss of $35 million attributable to CEG's economic interest in Clearway Energy LLC and a loss of $6 million attributable to CEG's interests in the Kawailoa, Oahu and Repowering partnerships, offset in part by income of $2 million attributable to noncontrolling interests with respect to its tax equity financing arrangements and the application of the HLBV method.

Liquidity and Capital Resources

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

53

Current Liquidity Position

As of June 30, 2020 and December 31, 2019, the Company's liquidity was approximately $855 million and $842 million, respectively, comprised of cash, restricted cash and availability under the Company's revolving credit facility.

(In millions)	June 30, 2020		December 31, 2019
Cash and cash equivalents:
Clearway Energy, Inc. and Clearway Energy LLC, excluding subsidiaries	$	59	$	30
Subsidiaries	116		125
Restricted cash:
Operating accounts	80		129
Reserves, including debt service, distributions, performance obligations and other reserves	161		133
Total cash, cash equivalents and restricted cash	416		417
Revolving credit facility availability	439		425
Total liquidity	$	855	$	842

The Company's liquidity includes $241 million and $262 million of restricted cash balances as of June 30, 2020 and December 31, 2019, respectively. Restricted cash consists primarily of funds to satisfy the requirements of certain debt arrangements and funds held within the Company's projects that are restricted in their use. As of June 30, 2020, these restricted funds were comprised of $80 million designated to fund operating expenses, approximately $20 million designated for current debt service payments, and $56 million restricted for reserves including debt service, performance obligations and other reserves, as well as capital expenditures. The remaining $85 million is held in distribution reserve accounts. As of June 30, 2020, $14 million of cash that was restricted pending the outcome of the PG&E Bankruptcy was reclassified into cash and cash equivalents.

As of June 30, 2020, the Company had no outstanding borrowings under the revolving credit facility and $56 million in letters of credit outstanding. During the six months ended June 30, 2020, the Company borrowed $265 million under the revolving credit facility, and subsequently repaid $265 million utilizing the proceeds from the 2028 Senior Notes and cash on hand.

During 2019, PG&E, one of the Company's largest customers filed for bankruptcy under Chapter 11 of the U.S. Bankruptcy Code. The PG&E Bankruptcy had no effect on availability under the Company’s revolving credit facility. However, the Company has non-recourse project-level debt related to each of its subsidiaries that sell their output to PG&E under long-term PPAs. The PG&E Bankruptcy filing was an event of default under the related financing agreements which caused uncertainty around the timing of when certain project-level cash distributions will be available to the Company. On July 1, 2020, PG&E emerged from bankruptcy and assumed the Company's contracts without modification. Subsequent to July 1, 2020, the Company collected all remaining receivables due from PG&E for pre-petition periods and as of July 31, 2020, $50 million of cash in distribution reserve accounts at subsidiaries affected by the PG&E Bankruptcy was distributed to Clearway Energy Operating LLC.

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

Credit Ratings

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

54

The following table summarizes the credit ratings for the Company and its Senior Notes as of June 30, 2020:

	S&P	Moody's
Clearway Energy, Inc.	BB	Ba2
5.750% Senior Notes, due 2025	BB	Ba2
5.000% Senior Notes, due 2026	BB	Ba2
4.750% Senior Notes, due 2028	BB	Ba2

Sources of Liquidity

The Company's principal sources of liquidity include cash on hand, cash generated from operations, proceeds from sales of assets, borrowings under new and existing financing arrangements and the issuance of additional equity and debt securities as appropriate given market conditions. As described in Item 1— Note 7, Long-term Debt, to this Form 10-Q and Note 10, Long-term Debt, to the consolidated financial statements included in the Company's 2019 Form 10-K, the Company's financing arrangements consist corporate level debt, which includes Senior Notes, Convertible Notes and the revolving credit facility; the ATM Program; and project-level financings for its various assets.

Revolving Credit Facility

The Company has a total of $439 million available under the revolving credit facility as of June 30, 2020. The facility will continue to be used for general corporate purposes including financing of future acquisitions and posting letters of credit.

2028 Senior Notes

On May 21, 2020, Clearway Energy Operating LLC completed the sale of an additional $250 million aggregate principal amount of the 2028 Senior Notes. The 2028 Senior Notes bear interest at 4.75% and mature on March 15, 2028. Interest on the 2028 Senior Notes is payable semi-annually on March 15 and September 15 of each year, and interest payments will commence on September 15, 2020. The 2028 Senior Notes are unsecured obligations of Clearway Energy Operating, LLC and are guaranteed by Clearway Energy LLC and by certain of Clearway Energy Operating LLC’s wholly owned current and future subsidiaries. The notes were issued at a price of 102% of par plus accrued interest from December 11, 2019. The net proceeds were utilized to repay the $45 million outstanding principal amount of the Company's 2020 Convertible Notes on June 1, 2020, as well as repay amounts outstanding under the Company’s revolving credit facility and for general corporate purposes.

ATM Sales

During the six months ended June 30, 2020, Clearway Energy, Inc. issued and sold 1,749,665 shares of Class C common stock for net proceeds of $38 million, which resulted in the completion of the shares of Class C common stock that were available to be issued under the ATM Program. The Company utilized the proceeds of the sales to acquire 1,749,665 Class C units of Clearway Energy LLC and, as a result, the Company currently owns 57.41% of the economic interests of Clearway Energy LLC, with CEG retaining 42.59% of the economic interests of Clearway Energy LLC.

Sale of Interest in RPV Holdco 1

On May 14, 2020, the Company sold its interests in RPV Holdco 1 LLC, or RPV Holdco, to a third party for net proceeds of approximately $75 million. The Company previously accounted for its interest in RPV Holdco as an equity method investment. The sale of the investment resulted in a gain of approximately $49 million.

Sale of Energy Center Dover LLC and Energy Center Smyrna LLC Assets

On March 3, 2020, the Company, through Thermal LLC, sold 100% of its interests in Energy Center Dover LLC and Energy Center Smyrna LLC to DB Energy Assets, LLC.

Uses of Liquidity

The Company's requirements for liquidity and capital resources, other than for operating its facilities, are categorized as: (i) debt service obligations, as described more fully in Item 1 — Note 7, Long-term Debt to the Consolidated Financial Statements; (ii) capital expenditures; (iii) acquisitions and investments; and (iv) cash dividends to investors.

55

Capital Expenditures

The Company's capital spending program is mainly focused on maintenance capital expenditures, consisting of costs to maintain the assets currently operating, such as costs to replace or refurbish assets, and growth capital expenditures consisting of costs to construct new assets, costs to complete the construction of assets where construction is in process, and capital expenditures related to acquiring additional thermal customers.

For the six months ended June 30, 2020, the Company used approximately $83 million to fund capital expenditures, including growth expenditures of $69 million, $46 million of which were incurred in connection with the repowering of the Elbow Creek and Wildorado facilities completed in the first quarter of 2020, as well as $6 million in connection with Oahu and Kawailoa Partnerships. The Company also incurred $12 million of growth capital expenditures in the Thermal segment in connection with various development projects. In addition, the Company incurred $14 million in maintenance capital expenditures. The Company estimates $32 million of maintenance expenditures for 2020. These estimates are subject to continuing review and adjustment. Actual capital expenditures may vary from these estimates.

Repowering Partnership II LLC

On May 11, 2020 the Company acquired CEG's remaining interest in Repowering 1.0, which includes the 161 MW Wildorado and 122 MW Elbow Creek wind projects, for cash consideration of $70 million.

Acquisitions and Investments

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

Investment in Mesquite Star Wind Project

On August 3, 2020, the Company entered into an agreement with CEG to acquire an interest in Mesquite Star Pledgor LLC, which owns the Mesquite Star wind project, a 419 MW utility scale wind project located in Fisher County, Texas for approximately $79 million. The acquisition is expected to close during the third quarter of 2020 and will be funded with existing liquidity. 

April 2020 Drop Down

On April 17, 2020, the Company entered into binding agreements to acquire and invest in a portfolio of the following projects: (i) 100% of the equity interests in Rattlesnake Flat, LLC, which owns the Rattlesnake Wind Project, a 144 net MW wind facility located in Adams County, WA; (ii) CEG's interest in Repowering Partnership II LLC (Repowering 1.0), which the Company acquired on May 11, 2020; and (iii) a new partnership with CEG to repower the Pinnacle Wind Project, a 55 net MW wind facility located in Mineral County, WV. The Company expects to invest approximately $241 million in corporate capital subject to closing adjustments for the above mentioned transactions.

Investment Partnership with CEG

During the six months ended June 30, 2020, the Company invested $10 million in distributed generation partnerships with CEG.

Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility

During the six months ended June 30, 2020, the Company borrowed $265 million under the revolving credit facility, and subsequently repaid $265 million utilizing the proceeds from the issuance of additional 2028 Senior Notes as described above and cash on hand.

2020 Convertible Notes

On June 1, 2020, the Company repaid its outstanding $45 million of 2020 Convertible Notes utilizing the proceeds from the issuance of additional 2028 Senior Notes as described above.

56

Cash Dividends to Investors

Clearway Energy, Inc. intends to use the amount of cash that it receives from its distributions from Clearway Energy LLC to pay quarterly dividends to the holders of its Class A common stock and Class C common stock. Clearway Energy LLC intends to distribute to its unit holders in the form of a quarterly distribution all of the CAFD it generates each quarter, less reserves for the prudent conduct of the business, including among others, maintenance capital expenditures to maintain the operating capacity of the assets. Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.

The following table lists the dividends paid on Clearway Energy, Inc.'s Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

On July 30, 2020, the Company declared quarterly dividends on its Class A common stock and Class C common stock of $0.3125 per share payable on September 15, 2020, to stockholders of record as of September 1, 2020.

57

Cash Flow Discussion

The following table reflects the changes in cash flows for the six months ended June 30, 2020, compared to the six months ended June 30, 2019:

	Six months ended June 30,
	2020		2019		Change
	(In millions)
Net cash provided by operating activities	$	184	$	150	$	34
Net cash provided by (used in) investing activities	40		(211)		251
Net cash used in financing activities	$	(225)	$	(226)	$	1

Net Cash Provided by Operating Activities

Changes to net cash provided by operating activities were driven by:	(In millions)
Increase in operating income adjusted for non-cash items	$	59
Decrease in working capital driven primarily by the timing of accounts receivable collections and payment of accounts payable	(13)
Decrease in dividend distributions received from unconsolidated affiliates	(12)
	$	34

Net Cash Provided by (Used in) Investing Activities

Changes to net cash provided by (used in) investing activities were driven by:	(In millions)
Acquisition of Duquesne University District Energy System on May 1, 2019	$	100
Proceeds received from sale of RPV Holdco, Energy Center Dover LLC and Energy Center Smyrna LLC in 2020	90
Payment to buy out an existing tax equity partner of Wind TE Holdco on January 2, 2019	19
Increase in cash due to consolidation of DGPV Holdco LLC in May 2020	17
Decrease in growth capital expenditures in the Renewables segment related to prior year expenditures for the repowering of Elbow Creek and Wildorado	13
Payment to acquire the Class A interest in the Oahu Partnership and Kawailoa Partnership in 2019	6
Increase in net distributions from unconsolidated affiliates in 2020	5
Other	1
	$	251

Net Cash Used in Financing Activities

Changes in net cash used in financing activities were driven by:	(In millions)
Increase in net contributions received from noncontrolling interests in 2020 compared to 2019, primarily from tax equity contributions in the Wildorado TE Holdco	$	165
Decrease in payments for long-term debt in 2020 compared to 2019 primarily due to 2019 repayment of 2019 Convertible Notes and Tapestry and Viento project level debt refinancing offset by 2020 repayments of Repowering Partnership construction debt, 2024 Senior Notes and 2020 Convertible Notes	69
Net proceeds received from issuance of common stock under the ATM Program in 2020	38
Decrease in payments for debt issuance costs due to project level debt refinancing in 2019	13
Decrease in proceeds from long-term debt in 2020 compared to 2019 primarily due to 2019 project level financing agreements at Repowering Partnership, Tapestry and Thermal offset by the 2028 Senior Note proceeds in 2020	(207)
Payment to buy out CEG's noncontrolling interest in Repowering Partnership II LLC on May 11, 2020	(70)
Increase in dividends paid to common stockholders in 2020	(7)
	$	1

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

As of December 31, 2019, the Company has a cumulative federal NOL carry forward balance of $1 billion for financial statement purposes, of which $0.9 billion will begin expiring between 2033 to 2037 if unutilized. The Company does not anticipate any federal income tax payments for 2020. Additionally, as of December 31, 2019, the Company has a cumulative state NOL carryforward balance of $649 million for financial statement purposes, which will expire between 2023 to 2039 if unutilized. The Company does not anticipate significant income tax payments for state and local jurisdictions in 2020. Based on the Company's current and expected NOL balances generated primarily by accelerated tax depreciation of its property, plant and equipment, the Company does not expect to pay significant federal income tax for a period of approximately ten years inclusive of any NOL generated after 2017 or later subject to an 80% limitation against future taxable income pursuant to the Tax Act.

As of December 31, 2019, the Company has an interest disallowance carry forward of $219 million as a result of the proposed §163(j) regulation, which was enacted as part of the Tax Cut and Jobs Act. The disallowed interest deduction has an indefinite carry forward period and any limitations on the utilization of this carry forward have been factored into our valuation allowance analysis. These are proposed regulations which are not final and are subject to change in the regulatory review process. On July 28, 2020, the Internal Revenue Service issued final regulations under §163(j), which limits the deduction for business interest expense. The Company is currently analyzing the impact that the regulations will have on its consolidated financial statements and related income tax calculations.

On March 27, 2020 the Coronavirus Aid, Relief, and Economic Security (CARES) Act, or CARES Act, was signed into law, which includes modifications to the business interest expense disallowance and net operating loss provisions. While the Company expects to utilize previously disallowed interest expense during 2020 as a result of the modifications, the Company does not expect the CARES Act to have a material impact on the consolidated financial statements. The Company will continue to assess the effects of the CARES Act and ongoing government guidance related to COVID-19 that may be issued.

On June 29, 2020, governor of California signed Assembly Bill 85, or AB 85, suspending California net operating loss (NOL) utilization and imposing a cap on the amount of business incentive credits companies can utilize, effective for tax years 2020, 2021, and 2022. After assessing the law change, the Company expects AB 85 to have an immaterial impact on the consolidated financial statements.

The Company is subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state jurisdictions. The Company is not subject to U.S. federal or state income tax examinations for years prior to 2013. The Company has no uncertain tax benefits.

Off-Balance Sheet Arrangements

Obligations under Certain Guarantee Contracts

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

Retained or Contingent Interests

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

Obligations Arising Out of a Variable Interest in an Unconsolidated Entity

Variable interest in equity investments — As of June 30, 2020, the Company has several investments with an ownership interest percentage of 50% or less in energy and energy-related entities that are accounted for under the equity method. DGPV Holdco 1 LLC, DGPV Holdco 2 LLC and GenConn are variable interest entities for which the Company is not the primary beneficiary. The Company's pro-rata share of non-recourse debt held by unconsolidated affiliates was approximately $660 million as of June 30, 2020. This indebtedness may restrict the ability of these subsidiaries to issue dividends or distributions to the Company.

Contractual Obligations and Commercial Commitments

The Company has a variety of contractual obligations and other commercial commitments that represent prospective cash requirements in addition to the Company's capital expenditure programs, as disclosed in the Company's 2019 Form 10-K.

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Fair Value of Derivative Instruments

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

The tables below disclose the activities of non-exchange traded contracts accounted for at fair value in accordance with ASC 820. Specifically, these tables disaggregate realized and unrealized changes in fair value; disaggregate estimated fair values at June 30, 2020, based on their level within the fair value hierarchy defined in ASC 820; and indicate the maturities of contracts at June 30, 2020. For a full discussion of the Company's valuation methodology of its contracts, see Derivative Fair Value Measurements in Item — 1 Note 5, Fair Value of Financial Instruments.

Derivative Activity (Losses) Gains	(In millions)
Fair value of contracts as of December 31, 2019	$	(92)
Contracts realized or otherwise settled during the period	9
Contracts acquired during the period	(29)
Changes in fair value	(121)
Fair value of contracts as of June 30, 2020	$	(233)

	Fair value of contracts as of June 30, 2020
	Maturity
Fair Value Hierarchy (Losses) Gains	1 Year or Less		Greater Than 1 Year to 3 Years		Greater Than 3 Years to 5 Years		Greater Than 5 Years		Total Fair Value
	(In millions)
Level 2	$	(41)	$	(69)	$	(40)	$	(66)	$	(216)
Level 3	—		(1)		(6)		(10)		(17)
Total	$	(41)	$	(70)	$	(46)	$	(76)	$	(233)

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

Critical Accounting Policies and Estimates

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

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

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

Recent Accounting Developments

See Item — 1 Note 2, Summary of Significant Accounting Policies, for a discussion of recent accounting developments.

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ITEM 3 — Quantitative and Qualitative Disclosures About Market Risk

The Company is exposed to several market risks in its normal business activities. Market risk is the potential loss that may result from market changes associated with the Company's power generation or with an existing or forecasted financial or commodity transaction. The types of market risks the Company is exposed to are commodity price risk, interest rate risk, liquidity risk, and credit risk. The following disclosures about market risk provide an update to, and should be read in conjunction with, Item 7A — Quantitative and Qualitative Disclosures About Market Risk, of the Company's 2019 Form 10-K.

Interest Rate Risk

The Company is exposed to fluctuations in interest rates through its issuance of variable rate debt. Exposures to interest rate fluctuations may be mitigated by entering into derivative instruments known as interest rate swaps, caps, collars and put or call options. These contracts reduce exposure to interest rate volatility and result in primarily fixed rate debt obligations when taking into account the combination of the variable rate debt and the interest rate derivative instrument. See Item 1 — Note 6, Derivative Instruments and Hedging Activities, for more information.

Most of the Company's project subsidiaries enter into interest rate swaps, intended to hedge the risks associated with interest rates on non-recourse project level debt. See Note 10, Long-term Debt, to the Company's audited consolidated financial statements for the year ended December 31, 2019 included in the 2019 Form 10-K for more information about interest rate swaps of the Company's project subsidiaries.

If all of the interest rate swaps had been discontinued on June 30, 2020, the Company would have owed the counterparties $230 million. Based on the credit ratings of the counterparties, the Company believes its exposure to credit risk due to nonperformance by counterparties to its hedge contracts to be insignificant.

The Company has long-term debt instruments that subject it to the risk of loss associated with movements in market interest rates. As of June 30, 2020, a 1% change in interest rates would result in an approximately $2 million change in market interest expense on a rolling twelve-month basis.

As of June 30, 2020, the fair value of the Company's debt was $6,917 million and the carrying value was $6,813 million. The Company estimates that a 1% decrease in market interest rates would have increased the fair value of its long-term debt by approximately $420 million.

Liquidity Risk

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

Commodity Price Risk

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

Based on a sensitivity analysis using simplified assumptions, the impact of a $0.50 per MMBtu increase or decrease in natural gas prices across the term of the derivative contracts would cause a change of approximately $1 million to the net value of derivatives as of June 30, 2020. The impact of a $0.50 per MWh increase or decrease in power prices across the term of the derivatives contracts would cause a change of approximately $1 million to the net value of power derivatives as of June 30, 2020.

Counterparty Credit Risk

Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; and (ii) the use of credit mitigation measures such as prepayment arrangements or volumetric limits. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties. See Item 1 - Note 1, Nature of Business, and Note 5, Fair Value of Financial Instruments, to the consolidated financial statements for more information about concentration of credit risk.

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ITEM 4 — Controls and Procedures

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures

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

Changes in Internal Control over Financial Reporting

There were no changes in the Company’s internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) during the quarter ended June 30, 2020 that materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

63

PART II - OTHER INFORMATION

ITEM 1 — LEGAL PROCEEDINGS

For a discussion of the material legal proceedings in which the Company was involved through June 30, 2020, see Note 13, Contingencies, to this Form 10-Q.

ITEM 1A — RISK FACTORS

Information regarding risk factors appears in Part I, Item 1A, Risk Factors, in the Company's 2019 Form 10-K, as supplemented by the risk factors disclosed in Part II, Item 1A, Risk Factors, in the Company's Quarterly Report on Form 10-Q for the quarter ended March 31, 2020. There have been no material changes in the Company's risk factors since those reported in its 2019 Form 10-K, as supplemented by the those reported in its Quarterly Report on Form 10-Q for the quarter ended March 31, 2020.

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

None.

ITEM 3 — DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4 — MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5 — OTHER INFORMATION

None. 

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ITEM 6 — EXHIBITS

Number	Description	Method of Filing
4.1	Eleventh Supplemental Indenture, dated as of July 17, 2020, among Clearway Energy Operating LLC, the guarantors named therein and Delaware Trust Company (as successor in interest to Law Debenture Trust Company of New York).	Incorporated herein by reference to Exhibit 4.1 to the Company's Current Report on Form 8-K filed on July 21, 2020.
4.2	Seventh Supplemental Indenture, dated as of July 17, 2020, among Clearway Energy Operating LLC, the guarantors named therein and Delaware Trust Company	Incorporated herein by reference to Exhibit 4.2 to the Company's Current Report on Form 8-K filed on July 21, 2020.
4.3	Third Supplemental Indenture, dated as of July 17, 2020, among Clearway Energy Operating LLC, the guarantors named therein and Delaware Trust Company.	Incorporated herein by reference to Exhibit 4.3 to the Company's Current Report on Form 8-K filed on July 21, 2020.
10.1*^	Purchase and Sale Agreement, dated as of April 17, 2020, by and between Clearway Energy Operating LLC and Clearway Renew LLC.	Incorporated herein by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on April 20, 2020.
10.2*^	Membership Interest Purchase Agreement, dated as of April 17, 2020, by and between Clearway Energy Operating LLC and SP Wind Holdings, LLC.	Incorporated herein by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K filed on April 20, 2020.
10.3*^	Membership Interest Purchase Agreement, dated as of April 17, 2020, by and between CWSP Wildorado Elbow Holding LLC and Wind TE Holdco LLC.	Incorporated herein by reference to Exhibit 10.3 to the Company's Current Report on Form 8-K filed on April 20, 2020.
10.4*^	Limited Liability Company Agreement of Pinnacle Repowering Partnership LLC, dated as of April 17, 2020.	Incorporated herein by reference to Exhibit 10.4 to the Company's Current Report on Form 8-K filed on April 20, 2020.
31.1	Rule 13a-14(a)/15d-14(a) certification of Christopher S. Sotos.	Filed herewith.
31.2	Rule 13a-14(a)/15d-14(a) certification of Chad Plotkin.	Filed herewith.
31.3	Rule 13a-14(a)/15d-14(a) certification of Mary-Lee Stillwell.	Filed herewith.
32	Section 1350 Certification.	Furnished herewith.
101 INS	Inline XBRL Instance Document.	Filed herewith.
101 SCH	Inline XBRL Taxonomy Extension Schema.	Filed herewith.
101 CAL	Inline XBRL Taxonomy Extension Calculation Linkbase.	Filed herewith.
101 DEF	Inline XBRL Taxonomy Extension Definition Linkbase.	Filed herewith.
101 LAB	Inline XBRL Taxonomy Extension Label Linkbase.	Filed herewith.
101 PRE	Inline XBRL Taxonomy Extension Presentation Linkbase.	Filed herewith.
104	Cover Page Interactive Data File (the cover page interactive data file does not appear in Exhibit 104 because its Inline XBRL tags are embedded within the Inline XBRL document).	Filed herewith.

*	Schedules and similar attachments to this Exhibit have been omitted pursuant to Item 601(a)(5) of Regulation S-K. The Company agrees to furnish supplementally a copy of any omitted schedule or exhibit to the U.S. Securities and Exchange Commission (the “SEC”) upon request.
^	Certain portions of this Exhibit have been redacted pursuant to Item 601(b)(10)(iv) of Regulation S-K. The omitted information is (i) not material and (ii) would likely cause competitive harm to the Company if publicly disclosed. The Company agrees to furnish supplementally an unredacted copy of this Exhibit to the SEC upon request.

65

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.

	CLEARWAY ENERGY, INC. (Registrant)
	/s/ CHRISTOPHER S. SOTOS
	Christopher S. Sotos
	Chief Executive Officer (Principal Executive Officer)
	/s/ CHAD PLOTKIN
	Chad Plotkin
	Chief Financial Officer (Principal Financial Officer)
	/s/ MARY-LEE STILLWELL
	Mary-Lee Stillwell
Date: August 6, 2020	Chief Accounting Officer (Principal Accounting Officer)

66

EX-31.1

EXHIBIT 31.1

CERTIFICATION

I, Christopher S. Sotos, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Clearway Energy, 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; and

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

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

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

/s/ CHRISTOPHER S. SOTOS

Christopher S. Sotos

Chief Executive Officer

(Principal Executive Officer)

Date: August 6, 2020

EX-31.2

EXHIBIT 31.2

CERTIFICATION

I, Chad Plotkin, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Clearway Energy, 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; and

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

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

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

/s/ CHAD PLOTKIN

Chad Plotkin

Chief Financial Officer

(Principal Financial Officer)

Date: August 6, 2020

EX-31.3

EXHIBIT 31.3

CERTIFICATION

I, Mary-Lee Stillwell, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Clearway Energy, 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; and

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

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

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

/s/ MARY-LEE STILLWELL

Mary-Lee Stillwell

Chief Accounting Officer

(Principal Accounting Officer)

Date: August 6, 2020

EX-32

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 Quarterly Report of Clearway Energy, Inc. on Form 10-Q for the quarter ended June 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Form 10-Q”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer's knowledge:

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

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

Date: August 6, 2020

/s/ CHRISTOPHER S. SOTOS

Christopher S. Sotos

Chief Executive Officer

(Principal Executive Officer)

/s/ CHAD PLOTKIN

Chad Plotkin

Chief Financial Officer

(Principal Financial Officer)

/s/ MARY-LEE STILLWELL

Mary-Lee Stillwell

Chief Accounting Officer

(Principal Accounting Officer) 

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

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

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Cover Page - shares	6 Months Ended
	Jun. 30, 2020	Jul. 31, 2020
Class of Stock [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	001-36002
Entity Registrant Name	Clearway Energy, Inc.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-1777204
Entity Address, Address Line One	300 Carnegie Center, Suite 300
Entity Address, City or Town	Princeton
Entity Address, State or Province	NJ
Entity Address, Postal Zip Code	08540
City Area Code	609
Local Phone Number	608-1525
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Entity Central Index Key	0001567683
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Common Class A
Class of Stock [Line Items]
Title of 12(b) Security	Class A Common Stock, par value $0.01
Trading Symbol	CWEN.A
Security Exchange Name	NYSE
Entity common stock, shares outstanding		34,599,645
Common Class B
Class of Stock [Line Items]
Entity common stock, shares outstanding		42,738,750
Common Class C
Class of Stock [Line Items]
Title of 12(b) Security	Class C Common Stock, par value $0.01
Trading Symbol	CWEN
Security Exchange Name	NYSE
Entity common stock, shares outstanding		80,602,613
Common Class D
Class of Stock [Line Items]
Entity common stock, shares outstanding		42,738,750

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Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Operating Revenues
Total operating revenues	$ 329	$ 284	$ 587	$ 501
Operating Costs and Expenses
Cost of operations	87	78	180	160
Depreciation, amortization and accretion	99	90	201	176
Impairment losses	0	19	0	19
General and administrative	12	7	21	13
Transaction and integration costs	0	1	1	2
Development costs	1	2	2	3
Total operating costs and expenses	199	197	405	373
Operating Income	130	87	182	128
Other Income (Expense)
Equity in earnings of unconsolidated affiliates	16	11	3	14
Gain on sale of unconsolidated affiliate	49	0	49	0
Other income, net	0	1	2	4
Loss on debt extinguishment	0	(1)	(3)	(1)
Interest expense	(93)	(130)	(260)	(231)
Total other expense, net	(28)	(119)	(209)	(214)
Income (Loss) Before Income Taxes	102	(32)	(27)	(86)
Income tax expense (benefit)	26	4	4	(3)
Net Income (Loss)	76	(36)	(31)	(83)
Less: Income (loss) attributable to noncontrolling interests and redeemable interests	29	(12)	(49)	(39)
Net Income (Loss) Attributable to Clearway Energy, Inc.	47	(24)	18	(44)
Common Class A
Other Income (Expense)
Net Income (Loss) Attributable to Clearway Energy, Inc.	$ 14	$ (8)	$ 6	$ (14)
Earnings (Losses) Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders
Weighted average number of Class A and Class C common shares outstanding - basic and diluted (in shares)	35	35	35	35
Losses per Weighted Average Class A and Class C Common Share - Basic and Diluted (in dollars per share)	$ 0.41	$ (0.22)	$ 0.16	$ (0.41)
Common stock, dividends, per share, cash paid (in dollars per share)	$ 0.21	$ 0.20	$ 0.42	$ 0.40
Common Class C
Other Income (Expense)
Net Income (Loss) Attributable to Clearway Energy, Inc.	$ 33	$ (16)	$ 13	$ (30)
Earnings (Losses) Per Share Attributable to Clearway Energy, Inc. Class A and Class C Common Stockholders
Weighted average number of Class A and Class C common shares outstanding - basic and diluted (in shares)	80	73	79	73
Losses per Weighted Average Class A and Class C Common Share - Basic and Diluted (in dollars per share)	$ 0.41	$ (0.22)	$ 0.16	$ (0.41)
Common stock, dividends, per share, cash paid (in dollars per share)	$ 0.21	$ 0.20	$ 0.42	$ 0.40

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Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 76	$ (36)	$ (31)	$ (83)
Other Comprehensive Income (Loss)
Unrealized gain (loss) on derivatives, net of income tax expense (benefit) of $1, $0, $(1), $0	4	5	(8)	3
Other comprehensive income (loss)	4	5	(8)	3
Comprehensive Income (Loss)	80	(31)	(39)	(80)
Less: Comprehensive income (loss) attributable to noncontrolling interests and redeemable interests	31	(10)	(53)	(38)
Comprehensive Income (Loss) Attributable to Clearway Energy, Inc.	$ 49	$ (21)	$ 14	$ (42)

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Consolidated Statements of Comprehensive Loss (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Unrealized loss on derivatives income tax expense (benefit)	$ 1	$ 0	$ (1)	$ 0

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Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Current Assets
Cash and cash equivalents	$ 175	$ 155
Restricted cash	241	262
Accounts receivable — trade	161	116
Accounts receivable — affiliate	0	2
Inventory	41	40
Prepayments and other current assets	36	33
Total current assets	654	608
Property, plant and equipment	6,256	6,063
Other Assets
Equity investments in affiliates	971	1,183
Intangible assets, net	1,393	1,428
Deferred income taxes	95	92
Right of use assets, net	257	223
Other non-current assets	110	103
Total other assets	2,826	3,029
Total Assets	9,736	9,700
Current Liabilities
Current portion of long-term debt	357	1,824
Accounts payable — trade	41	74
Accounts payable — affiliate	21	31
Derivative instruments	41	16
Accrued interest expense	55	41
Accrued expenses and other current liabilities	40	71
Total current liabilities	555	2,057
Other Liabilities
Long-term debt	6,377	4,956
Derivative instruments	192	76
Long-term lease liabilities	260	227
Other non-current liabilities	120	121
Total non-current liabilities	6,949	5,380
Total Liabilities	7,504	7,437
Commitments and Contingencies
Stockholders' Equity
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued	0	0
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 200,678,701 shares issued and outstanding (Class A 34,599,645, Class B 42,738,750, Class C 80,601,556, Class D 42,738,750) at June 30, 2020 and 198,819,999 shares issued and outstanding (Class A 34,599,645, Class B 42,738,750, Class C 78,742,854, Class D 42,738,750) at December 31, 2019	1	1
Additional paid-in capital	1,934	1,936
Accumulated deficit	(54)	(72)
Accumulated other comprehensive loss	(19)	(15)
Noncontrolling interest	370	413
Total Stockholders' Equity	2,232	2,263
Total Liabilities and Stockholders' Equity	$ 9,736	$ 9,700

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Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 30, 2020	Dec. 31, 2019
Par value - preferred stock (in usd per share)	$ 0.01	$ 0.01
Preferred stock, authorized (in shares)	10,000,000	10,000,000
Preferred stock issued (in shares)	0	0
Common stock, authorized (in shares)	3,000,000,000	3,000,000,000
Common stock issued (in shares)	200,678,701	198,819,999
Common stock outstanding (in shares)	200,678,701	198,819,999
Common Class A
Par value - common stock (in usd per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	500,000,000	500,000,000
Common stock issued (in shares)	34,599,645	34,599,645
Common stock outstanding (in shares)	34,599,645	34,599,645
Common Class B
Par value - common stock (in usd per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	500,000,000	500,000,000
Common stock issued (in shares)	42,738,750	42,738,750
Common stock outstanding (in shares)	42,738,750	42,738,750
Common Class C
Par value - common stock (in usd per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	1,000,000,000	1,000,000,000
Common stock issued (in shares)	80,601,556	78,742,854
Common stock outstanding (in shares)	80,601,556	78,742,854
Common Class D
Par value - common stock (in usd per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	1,000,000,000	1,000,000,000
Common stock issued (in shares)	42,738,750	42,738,750
Common stock outstanding (in shares)	42,738,750	42,738,750

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Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Cash Flows from Operating Activities
Net loss	$ (31)	$ (83)
Adjustments to reconcile net loss to net cash provided by operating activities:
Equity in earnings of unconsolidated affiliates	(3)	(14)
Distributions from unconsolidated affiliates	10	22
Depreciation, amortization and accretion	201	176
Amortization of financing costs and debt discounts	8	7
Amortization of intangibles and out-of-market contracts	45	35
Loss on debt extinguishment	3	1
Right-of-use asset amortization	(1)	3
Gain on sale of unconsolidated affiliate	(49)	0
Impairment losses	0	19
Changes in deferred income taxes	4	(3)
Changes in derivative instruments	100	70
Loss on disposal of asset components	0	7
Changes in prepaid and accrued liabilities for tolling agreements	(77)	(60)
Changes in other working capital	(26)	(30)
Net Cash Provided by Operating Activities	184	150
Cash Flows from Investing Activities
Acquisitions	0	(100)
Partnership interest acquisition	0	(6)
Buyout of Wind TE Holdco noncontrolling interest	0	(19)
Consolidation of DGPV Holdco 3 LLC	17	0
Capital expenditures	(83)	(96)
Return of investment from unconsolidated affiliates	23	17
Investments in unconsolidated affiliates	(10)	(9)
Proceeds from sale of assets	90	0
Insurance proceeds	3	0
Other	0	2
Net Cash Provided by (Used in) Investing Activities	40	(211)
Cash Flows from Financing Activities
Net contributions (distributions) from noncontrolling interests	154	(11)
Buyout of Repowering Partnership II LLC noncontrolling interest	(70)	0
Net proceeds from the issuance of common stock	38	0
Payments of dividends and distributions	(84)	(77)
Payments of debt issuance costs	(2)	(15)
Proceeds from the revolving credit facility	265	22
Payments for the revolving credit facility	(265)	(22)
Proceeds from the issuance of long-term debt	286	493
Payments for long-term debt	(547)	(616)
Net Cash Used in Financing Activities	(225)	(226)
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(1)	(287)
Cash, Cash Equivalents and Restricted Cash at beginning of period	417	583
Cash, Cash Equivalents and Restricted Cash at end of period	$ 416	$ 296

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Consolidated Statements of Stockholders' Equity - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	DGPV Holdco 3	Repowering Partnership II LLC	Preferred Stock	Common Stock	Additional Paid-In Capital	Accumulated Deficit	Accumulated Deficit Cumulative Effect, Period of Adoption, Adjustment	Accumulated Other Comprehensive Loss	Noncontrolling Interest	Noncontrolling Interest Cumulative Effect, Period of Adoption, Adjustment	Noncontrolling Interest DGPV Holdco 3	Noncontrolling Interest Repowering Partnership II LLC	CEG	CEG Noncontrolling Interest	Tax Equity Investors	Tax Equity Investors Noncontrolling Interest
Balance at beginning of period at Dec. 31, 2018	$ 2,224	$ (3)			$ 0	$ 1	$ 1,897	$ (58)	$ (2)	$ (18)	$ 402	$ (1)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(47)							(20)			(27)
Unrealized loss on derivatives, net of tax	(2)									(1)	(1)
Contributions, non-cash	12										12
Capital contributions, net of distributions, cash																	$ 19	$ 19
Buyout of noncontrolling interest	(19)						(5)				(14)
Common stock dividends and distributions to CEG	(39)						(22)				(17)
Balance at end of period at Mar. 31, 2019	2,145				0	1	1,870	(80)		(19)	373
Balance at beginning of period at Dec. 31, 2018	2,224	$ (3)			0	1	1,897	(58)	$ (2)	(18)	402	$ (1)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(83)
Balance at end of period at Jun. 30, 2019	2,054				0	1	1,852	(105)		(16)	322
Balance at beginning of period at Mar. 31, 2019	2,145				0	1	1,870	(80)		(19)	373
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(36)							(24)			(12)
Unrealized loss on derivatives, net of tax	5									3	2
Contributions, non-cash															$ 6	$ 6
Stock-based compensation	0						1	(1)
Non-cash adjustment for change in tax basis of assets	2						2
Distributions to tax equity investors, non-cash	(30)										(30)
Common stock dividends and distributions to CEG	(38)						(21)				(17)
Balance at end of period at Jun. 30, 2019	2,054				0	1	1,852	(105)		(16)	322
Balance at beginning of period at Dec. 31, 2019	2,263				0	1	1,936	(72)		(15)	413
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(107)							(29)			(78)
Unrealized loss on derivatives, net of tax	(12)									(6)	(6)
Capital contributions, net of distributions, cash	150										150				4	4
Net proceeds from the issuance of common stock under the ATM Program	10						10
Distributions to tax equity investors, non-cash																	(2)	(2)
Common stock dividends and distributions to CEG	(42)						(24)				(18)
Balance at end of period at Mar. 31, 2020	2,264				0	1	1,922	(101)		(21)	463
Balance at beginning of period at Dec. 31, 2019	2,263				0	1	1,936	(72)		(15)	413
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(31)
Balance at end of period at Jun. 30, 2020	2,232				0	1	1,934	(54)		(19)	370
Balance at beginning of period at Mar. 31, 2020	2,264				0	1	1,922	(101)		(21)	463
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	76							47			29
Unrealized loss on derivatives, net of tax	4									2	2
Contributions, non-cash															8	8
Capital contributions, net of distributions, cash															$ 2	$ 2
Distributions to tax equity interests, net of contributions, cash.																	$ (3)	$ (3)
Stock-based compensation	1						1
Non-cash adjustment for change in tax basis of assets	7						7
Net proceeds from the issuance of common stock under the ATM Program	28						28
Buyout of noncontrolling interest			$ (43)	$ (70)									$ (43)	$ (70)
Common stock dividends and distributions to CEG	(42)						(24)				(18)
Balance at end of period at Jun. 30, 2020	$ 2,232				$ 0	$ 1	$ 1,934	$ (54)		$ (19)	$ 370

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Nature of Business

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Business

Nature of Business

Clearway Energy, Inc., together with its consolidated subsidiaries, or the Company, is a publicly-traded energy infrastructure investor in and owner of modern, sustainable and long-term contracted assets across North America. The Company is sponsored by GIP III Zephyr Acquisition Partners, L.P. through its portfolio company, CEG. GIP is an independent fund manager that invests in infrastructure assets in energy and transport sectors.

The Company’s environmentally-sound asset portfolio includes over 5,991 MW of wind, solar and natural gas-fired power generation facilities. Through this diversified and contracted portfolio, the Company endeavors to provide its investors with stable and growing dividend income. Nearly all of these assets sell substantially all of their output pursuant to long-term offtake agreements with creditworthy counterparties. The weighted average remaining contract duration of these offtake agreements was approximately 13 years as of June 30, 2020 based on CAFD. The Company also owns thermal infrastructure assets with an aggregate steam and chilled water capacity of 1,453 net MWt and electric generation capacity of 36 net MW. These thermal infrastructure assets provide steam, hot and/or chilled water, and, in some instances, electricity to commercial businesses, universities, hospitals and governmental units in multiple locations, principally through long-term contracts or pursuant to rates regulated by state utility commissions.

The Company consolidates the results of Clearway Energy LLC through its controlling interest, with CEG's interest shown as noncontrolling interest in the financial statements. The holders of the Company's outstanding shares of Class A and Class C common stock are entitled to dividends as declared. CEG receives its distributions from Clearway Energy LLC through its ownership of Clearway Energy LLC Class B and Class D units.

As a result of the Class C common stock issuance under the ATM Program during the six months ended June 30, 2020, the Company owns 57.41% of the economic interests of Clearway Energy LLC, with CEG retaining 42.59% of the economic interests of Clearway Energy LLC as of June 30, 2020. For further discussion, see Note 9, Changes in Capital Structure.

The following table represents the structure of the Company as of June 30, 2020:

Basis of Presentation

The accompanying unaudited interim consolidated financial statements have been prepared in accordance with the SEC’s regulations for interim financial information and with the instructions to Form 10-Q. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. The following notes should be read in conjunction with the accounting policies and other disclosures as set forth in the notes to the consolidated financial statements included in the Company's 2019 Form 10-K. Interim results are not necessarily indicative of results for a full year.

In the opinion of management, the accompanying unaudited interim consolidated financial statements contain all material adjustments consisting of normal and recurring accruals necessary to present fairly the Company's consolidated financial position as of June 30, 2020, and the results of operations, comprehensive income (loss) and cash flows for the six months ended June 30, 2020 and 2019.

PG&E Bankruptcy Update

During 2019, PG&E, one of the Company's largest customers, filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the Northern District of California, or the Bankruptcy Court. On January 31, 2020, PG&E filed with the Bankruptcy Court a Chapter 11 plan of reorganization, as amended, or the PG&E Plan. On June 20, 2020, the Bankruptcy Court confirmed the PG&E Plan, which provided for PG&E to assume all of its PPAs with the Company. On July 1, 2020, PG&E emerged from bankruptcy and assumed the Company's contracts without modification. In addition, PG&E paid to the Company's applicable projects the portion of the invoices corresponding to the electricity delivered for the period between January 1 and January 28, 2019. These invoices related to the pre-petition period services and any payment therefore required the approval by the Bankruptcy Court. A description of changes to the financial statements resulting from PG&E's emergence from bankruptcy is noted below in Note 2, Summary of Significant Accounting Policies, Note 5, Fair Value of Financial Instruments and Note 7, Long-term Debt.

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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2020

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Use of Estimates

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

Cash and Cash Equivalents, and Restricted Cash

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase. Cash and cash equivalents held at project subsidiaries was $116 million and $125 million as of June 30, 2020 and December 31, 2019, respectively. After PG&E emerged from bankruptcy on July 1, 2020, $50 million of cash distributions were paid out of distribution reserve accounts at subsidiaries affected by the PG&E Bankruptcy to Clearway Energy Operating LLC as of July 31, 2020.

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

	June 30, 2020		December 31, 2019
	(In millions)
Cash and cash equivalents	$	175	$	155
Restricted cash	241		262
Cash, cash equivalents and restricted cash shown in the statement of cash flows	$	416	$	417

Restricted cash consists primarily of funds held to satisfy the requirements of certain debt agreements and funds held within the Company's projects that are restricted in their use. As of June 30, 2020, these restricted funds were comprised of $80 million designated to fund operating expenses, approximately $20 million designated for current debt service payments, and $56 million restricted for reserves including debt service, performance obligations and other reserves, as well as capital expenditures. The remaining $85 million is held in distributions reserve accounts. As of June 30, 2020, $14 million of cash that was restricted pending the outcome of the PG&E Bankruptcy was reclassified into cash and cash equivalents.

Accumulated Depreciation, Accumulated Amortization

The following table presents the accumulated depreciation included in the property, plant and equipment, net, and accumulated amortization included in intangible assets, net, respectively, as of June 30, 2020 and December 31, 2019:

	June 30, 2020		December 31, 2019
	(In millions)
Property, Plant and Equipment Accumulated Depreciation	$	2,036	$	1,880
Intangible Assets Accumulated Amortization	439		394

Dividends to Class A and Class C common stockholders

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.

On July 30, 2020, the Company declared quarterly dividends on its Class A common stock and Class C common stock of $0.3125 per share payable on September 15, 2020, to stockholders of record as of September 1, 2020.

Noncontrolling Interests

Clearway Energy LLC Distributions to CEG

The following table lists distributions paid to CEG during the period ended June 30, 2020 on Clearway Energy LLC's Class B and D units:

	Second Quarter 2020		First Quarter 2020
Distributions per Class B Unit	$	0.21	$	0.21
Distributions per Class D Unit	$	0.21	$	0.21

On July 30, 2020, Clearway Energy LLC declared a distribution on its Class B and Class D units of $0.3125 per unit payable on September 15, 2020 to unit holders of record as of September 1, 2020.

Revenue Recognition

Revenue from Contracts with Customers

The Company applies the guidance in ASC 606, Revenue from Contracts with Customers, or Topic 606, when recognizing revenue associated with its contracts with customers. The Company's policies with respect to its various revenue streams are detailed below. In general, the Company applies the invoicing practical expedient to recognize revenue for the revenue streams detailed below, except in circumstances where the invoiced amount does not represent the value transferred to the customer.

Thermal Revenues

Steam and chilled water revenue is recognized as the Company transfers the product to the customer, based on customer usage as determined by meter readings taken at month-end. Some locations read customer meters throughout the month and recognize estimated revenue for the period between meter read date and month-end. For thermal contracts, the Company’s performance obligation to deliver steam and chilled water is satisfied over time and revenue is recognized based on the invoiced amount. The Thermal Business subsidiaries collect, and remit state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes are presented on a net basis in the income statement.

As contracts for steam and chilled water are long-term contracts, the Company has performance obligations under these contracts that have not yet been satisfied. These performance obligations have transaction prices that are both fixed and variable, and which vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the Company cannot accurately estimate the amount of its unsatisfied performance obligations as it will vary based on customer usage, which will depend on factors such as weather and customer activity.

Power Purchase Agreements

The majority of the Company’s revenues are obtained through PPAs or other contractual agreements. Energy, capacity and where applicable, renewable attributes, from the majority of the Company’s renewable energy assets and certain conventional energy plants is sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer. The majority of these PPAs are accounted for as leases. Previously ASC 840, and currently ASC 842, requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. Management's judgment is required in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or capital lease.

Renewable Energy Credits

Renewable energy credits, or RECs, are usually sold through long-term PPAs. Revenue from the sale of self-generated RECs is recognized when the related energy is generated and simultaneously delivered even in cases where there is a certification lag as it has been deemed to be perfunctory.

In a bundled contract to sell energy, capacity and/or self-generated RECs, all performance obligations are deemed to be delivered at the same time and hence, timing of recognition of revenue for all performance obligations is the same and occurs over time. In such cases, it is often unnecessary to allocate transaction price to multiple performance obligations.

Disaggregated Revenues  

The following tables represent the Company’s disaggregation of revenue from contracts with customers along with the reportable segment for each category for the three and six months ended June 30, 2020 and 2019 respectively:

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	1	$	195	$	22	$	218
Capacity revenue(a)	112		—		12		124
Contract amortization	(6)		(16)		—		(22)
Other revenue	—		4		8		12
Mark-to-market for economic hedges	—		(3)		—		(3)
Total operating revenue	107		180		42		329
Less: Mark-to-market for economic hedges	—		3		—		3
Less: Lease revenue	(113)		(181)		—		(294)
Less: Contract amortization	6		16		—		22
Total revenue from contracts with customers	$	—	$	18	$	42	$	60

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	181	$	—	$	182
Capacity revenue	112		—		—		112
Total	$	113	$	181	$	—	$	294

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	3	$	320	$	50	$	373
Capacity revenue(a)	219		—		26		245
Contract amortization	(12)		(31)		(1)		(44)
Other revenue	—		6		15		21
Mark-to-market for economic hedges	—		(8)		—		(8)
Total operating revenue	210		287		90		587
Less: Mark-to-market for economic hedges	—		8		—		8
Less: Lease revenue	(222)		(296)		(1)		(519)
Less: Contract amortization	12		31		1		44
Total revenue from contracts with customers	$	—	$	30	$	90	$	120

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	3	$	296	$	1	$	300
Capacity revenue	219		—		—		219
Total	$	222	$	296	$	1	$	519

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	1	$	166	$	26	$	193
Capacity revenue(a)	85		—		14		99
Contract amortization	(2)		(15)		—		(17)
Other revenue	—		2		7		9
Total operating revenue	84		153		47		284
Less: Lease revenue	(86)		(157)		(1)		(244)
Less: Contract amortization	2		15		—		17
Total revenue from contracts with customers	$	—	$	11	$	46	$	57

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	157	$	1	$	159
Capacity revenue	85		—		—		85
Total	$	86	$	157	$	1	$	244

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	2	$	274	$	58	$	334
Capacity revenue(a)	164		—		27		191
Contract amortization	(3)		(30)		(1)		(34)
Mark-to-market for economic hedges	—		(7)		—		(7)
Other revenue	—		4		13		17
Total operating revenue	163		241		97		501
Less: Mark-to-market for economic hedges	—		7		—		7
Less: Lease revenue	(166)		(256)		(1)		(423)
Less: Contract amortization	3		30		1		34
Total revenue from contracts with customers	$	—	$	22	$	97	$	119

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	2	$	256	$	1	$	259
Capacity revenue	164		—		—		164
Total	$	166	$	256	$	1	$	423

Contract Amortization

Assets and liabilities recognized from power sales agreements assumed through acquisitions related to the sale of electric capacity and energy in future periods for which the fair value has been determined to be significantly less (more) than market are amortized to revenue over the term of each underlying contract based on actual generation and/or contracted volumes or on a straight-line basis, where applicable.

Contract Balances

The following table reflects the contract assets and liabilities included on the Company’s balance sheet as of June 30, 2020:

(In millions)
Accounts receivable, net - Contracts with customers	$	39
Accounts receivable, net - Leases	122
Total accounts receivable, net	$	161

Recently Issued Accounting Standards Adopted in 2020

In March 2020, the FASB issued ASU 2020-4, Facilitation of the Effects of Reference Rate Reform on Financial Reporting. The amendments provide for optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria is met. These amendments apply only to contracts that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. The guidance is effective for all entities as of March 12, 2020 through December 31, 2022. The Company intends to apply the amendments to all its eligible contract modifications where applicable.

Recently Issued Accounting Standards Not Yet Adopted

In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. The amendments in this ASU simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740, Income Taxes. The amendments also improve consistent application of and simplify GAAP for other areas of Topic 740 by clarifying and amending existing guidance. The guidance is effective January 1, 2021, with early adoption permitted. The Company does not expect the effect of the new guidance to be material on its consolidated financial statements.

Reclassification

Certain prior year amounts have been reclassified for comparative purposes.

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Acquisitions and Dispositions

6 Months Ended

Jun. 30, 2020

Business Combinations [Abstract]

Acquisitions and Dispositions

Acquisition and Dispositions

2019 Acquisition

Duquesne University District Energy System Acquisition — On May 1, 2019, the Company, through its indirect subsidiary ECP Uptown Campus LLC, acquired the Duquesne University district energy system, totaling 87 combined MWt, located in Pittsburgh, PA. As part of the acquisition, Duquesne University entered into a 40-year Energy Services Agreement through which ECP Uptown Campus LLC will fulfill the university's electricity, chilled water and steam requirements in exchange for monthly capacity payments. The transaction is reflected in the Company's Thermal segment. The total investment for the project was approximately $107 million.

2020 Dispositions

Sale of RPV Holdco 1 LLC — On May 14, 2020, the Company sold its interests in RPV Holdco 1 LLC, or RPV Holdco, to a third party for net proceeds of approximately $75 million. The Company previously accounted for its interest in RPV Holdco as an equity method investment. The sale of the investment resulted in a gain of approximately $49 million.

Sale of Energy Center Dover LLC and Energy Center Smyrna LLC Assets — On March 3, 2020, the Company, through Clearway Thermal LLC, sold 100% of its interests in Energy Center Dover LLC and Energy Center Smyrna LLC to DB Energy Assets, LLC.

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Investments Accounted for by the Equity Method and Variable Interest Entities

6 Months Ended

Jun. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

Investments Accounted for by the Equity Method and Variable Interest Entities

Investments Accounted for by the Equity Method and Variable Interest Entities

Entities that are Consolidated

The Company has a controlling financial interest in certain entities which have been identified as VIEs under ASC 810, Consolidations, or ASC 810. These arrangements are primarily related to tax equity arrangements entered into with third parties in order to monetize certain tax credits associated with wind and solar facilities, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the consolidated financial statements included in the Company's 2019 Form 10-K.

Summarized financial information for the Company's consolidated VIEs consisted of the following as of June 30, 2020:

(In millions)	Oahu Solar Partnership		Kawailoa Partnership		Elbow Creek TE Holdco		Wildorado TE Holdco		DGPV Holdco 3		Alta TE Holdco		Spring Canyon		Buckthorn Renewables LLC		Other (a)
Other current and non-current assets	$	26	$	23	$	10	$	19	$	63	$	61	$	3	$	3	$	5
Property, plant and equipment	183		144		104		249		330		369		84		211		8
Intangible assets	—		—		1		—		1		231		—		—		—
Total assets	209		167		115		268		394		661		87		214		13
Current and non-current liabilities	127		117		26		12		281		44		6		7		3
Total liabilities	127		117		26		12		281		44		6		7		3
Noncontrolling interest	30		40		75		109		6		44		35		66		—
Net assets less noncontrolling interests	$	52	$	10	$	14	$	147	$	107	$	573	$	46	$	141	$	10

^(a) Other is comprised of Crosswinds and Hardin projects.

The discussion below describes material changes to VIEs during the six months ended June 30, 2020.

DGPV Holdco 3 LLC

DGPV Holdco 3 owns approximately 113 MW of distributed solar capacity, based on cash to be distributed, with a weighted average remaining contract life of approximately 21 years as of June 30, 2020. On May 29, 2020, the final construction projects for DGPV Holdco 3 were placed in service which resulted in a reconsideration event for consolidation of the entity. Upon the reconsideration event, the Company determined that it was the primary beneficiary of DGPV Holdco 3, as it is entitled to 99% of allocations of income and cash distributions from the entity. As such, effective on May 29, 2020, the Company consolidates DGPV Holdco 3, and shows the interest owned by CEG as noncontrolling interest. DGPV Holdco 3 owns an interest in two tax equity funds with tax equity investors, both of which are consolidated by DGPV Holdco 3, and the interests owned by the tax equity investors are shown as noncontrolling interests. The Company removed its investment in DGPV Holdco 3 of $155 million as of May 29, 2020 and recorded the difference between the net assets consolidated and the investment balance as a reduction to noncontrolling interests.

The following table shows the balances that were consolidated effective on May 29, 2020:

(In millions)	May 29, 2020
Current assets	$	32
Property, plant and equipment	330
Intangible assets	1
Other non-current assets	37
Total assets	$	400
Debt	206
Other current and non-current liabilities	84
Total liabilities	$	290
Noncontrolling interests and redeemable noncontrolling interests	6
Net assets less noncontrolling interests	$	104

Prior to the reconsideration event described above, the Company invested $10 million of cash in DGPV Holdco 3 during the six months ended June 30, 2020.

Repowering Partnership II LLC

On May 11, 2020, the Company acquired CEG's interest in Repowering Partnership II LLC, for cash consideration of $70 million. Repowering Partnership II LLC is no longer a VIE and subsequent to the acquisition, is a wholly-owned subsidiary of the Company. Repowering Partnership II LLC continues to own interests in two VIEs, Wildorado Repowering Tax Equity Holdco LLC, or Wildorado TE Holdco, and Elbow Creek Repowering Tax Equity Holdco LLC, or Elbow Creek TE Holdco. The Company removed the related noncontrolling interest balance of $8 million and recorded the difference between the cash paid and the noncontrolling interest balance removed as a reduction to noncontrolling interests.

On February 7, 2020, a third party tax equity investor purchased 100% of the Class A membership interests in Wildorado TE Holdco, for $148 million. In addition, the Company contributed $112 million to Wildorado TE Holdco. The combined proceeds were used to repay construction debt under the Repowering Partnership Holdco credit agreement, as described in Note 7, Long-term Debt. The third party tax equity investor, or Wildorado Investor, will receive 99% of allocations of taxable income and other items until the Wildorado Investor obtains a specified return on its initial investment, or the last day of the PTC period, whichever occurs sooner. At such time, the allocations to the Wildorado Investor will change to 5%. Until such time, the Wildorado Investor will receive a variable percentage of cash distributions. Wildorado TE Holdco is a VIE and the Repowering Partnership II LLC is the primary beneficiary through its position as managing member. As a result, the Company consolidates Wildorado TE Holdco, with the Wildorado Investor's interest shown as noncontrolling interest. In connection with the Wildorado TE Holdco closing, the allocations of income at Repowering Partnership II LLC changed to 60.14% for Wind TE Holdco LLC (the Company member) and 39.86% for CWSP Wildorado Elbow Holding LLC (the CEG member). As noted above, CEG no longer has an interest in Repowering Partnership II LLC as of June 30, 2020.

The Company utilizes the HLBV method to determine the net income or loss allocated to tax equity noncontrolling interest. The Company recorded a loss of $8 million and $36 million attributable to the noncontrolling interest of Wildorado TE Holdco for the three and six months ending June 30, 2020 and recorded a loss of $6 million and $8 million attributable to the noncontrolling interest of Elbow Creek TE Holdco for the three and six months ending June 30, 2020, respectively.

Entities that are not Consolidated

The Company has interests in entities that are considered VIEs under ASC 810, but for which it is not considered the primary beneficiary. The Company accounts for its interests in these entities under the equity method of accounting, as further described in Note 5, Investments Accounted for by the Equity Method and Variable Interest Entities, to the consolidated financial statements included in the Company's 2019 Form 10-K.

The Company's maximum exposure to loss as of June 30, 2020 is limited to its equity investment in the unconsolidated entities, as further summarized in the table below:

Name	Economic Interest	Investment Balance
		(In millions)
Utah Solar Portfolio (a)	50%	$	276
Desert Sunlight (b)	25%	276
Agua Caliente Solar (b)	16%	99
GenConn	50%	92
DGPV Holdco 1 LLC (c)	95%	82
DGPV Holdco 2 LLC (c)	95%	63
San Juan Mesa	75%	45
Elkhorn Ridge	66.7%	42
Avenal (b)	50%	(4)
		$	971

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

^(b) Entities that have PPAs with PG&E. For further update on PG&E Bankruptcy see Note 1— Nature of Business.

^(c) Economic interest based on cash to be distributed. DGPV Holdco 1 LLC and DGPV Holdco 2 LLC, are tax equity structures and VIEs.

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

	Three months ended June 30,				Six months ended June 30,
(In millions)	2020		2019		2020		2019
Income Statement Data:
DGPV Holdco 3 (a)
Operating revenue	$	7	$	8	$	14	$	12
Operating income	4		4		6		5
Net income (loss)	4		9		(12)		9
RPV Holdco (b)
Operating revenue	2		3		6		7
Operating income	—		—		—		1
Net (loss) income	—		(2)		3		(3)
GenConn
Operating revenue	15		15		29		31
Operating income	7		7		13		14
Net income	4		5		8		9
Desert Sunlight
Operating revenue	59		57		95		92
Operating income	42		37		63		53
Net income	25		16		28		20
Other (c)
Operating revenue	81		79		136		131
Operating income	40		34		52		44
Net income	$	32	$	20	$	22	$	16

^(a) Year to date as of the reconsideration event on May 29, 2020.

^(b) Year to date as of the sale on May 14, 2020 as described in Note 3, Acquisition and Dispositions.

^(c) Includes Agua Caliente, DGPV Holdco 1, DGPV Holdco 2, Elkhorn Ridge, Utah Solar Portfolio and San Juan Mesa.

	As of June 30, 2020		As of December 31, 2019
Balance Sheet Data:	(In millions)
DGPV Holdco 3 (a)
Current assets	$	—	$	39
Non-current assets	—		371
Current liabilities	—		61
Non-current liabilities	—		216
Redeemable noncontrolling interest	—		(1)
RPV Holdco (a)
Current assets	—		2
Non-current assets	—		162
Current liabilities	—		1
Non-current liabilities	—		8
Redeemable noncontrolling interest	—		31
GenConn
Current assets	36		37
Non-current assets	352		342
Current liabilities	14		16
Non-current liabilities	190		176
Desert Sunlight
Current assets	261		209
Non-current assets	1,271		1,296
Current liabilities	545		545
Non-current liabilities	482		484
Other (b)
Current assets	275		220
Non-current assets	2,807		2,879
Current liabilities	71		785
Non-current liabilities	991		277

^(a) As of June 30, 2020, these are no longer equity method investments

^(b) Includes Agua Caliente, DGPV Holdco 1, DGPV Holdco 2, Elkhorn Ridge, Utah Solar Portfolio and San Juan Mesa.

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Fair Value of Financial Instruments

6 Months Ended

Jun. 30, 2020

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value of Financial Instruments

Fair Value Accounting under ASC 820

ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

•Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date.

•Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

•Level 3—unobservable inputs for the asset or liability only used when there is little, if any, market activity for the asset or liability at the measurement date.

In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement.

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

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

	As of June 30, 2020				As of December 31, 2019
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Long-term debt, including current portion (a)	$	6,813	$	6,917	$	6,858	$	6,957

^(a) Excludes net debt issuance costs, which are recorded as a reduction to long-term debt on the Company's consolidated balance sheets.

The fair value of the Company's publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of non-publicly traded long-term debt of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy. The following table presents the level within the fair value hierarchy for long-term debt, including current portion as of June 30, 2020 and December 31, 2019:

	As of June 30, 2020				As of December 31, 2019
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	1,849	$	5,068	$	1,736	$	5,221

Recurring Fair Value Measurements

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

	As of June 30, 2020				As of December 31, 2019
	Fair Value (a)				Fair Value (a)
(In millions)	Level 2		Level 3		Level 2		Level 3
Derivative liabilities:
Commodity contracts	$	1	$	17	$	—	$	9
Interest rate contracts	215		—		83		—
Total liabilities	$	216	$	17	$	83	$	9

^(a) There were no derivative assets classified as Level 1, Level 2 or Level 3 and no liabilities classified as Level 1 as of June 30, 2020 and as of December 31, 2019.

The following table reconciles the beginning and ending balances for instruments that are recognized at fair value in the condensed consolidated financial statements using significant unobservable inputs:

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
(In millions)	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)				Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
Beginning balance	$	(14)	$	(7)	$	(9)	$	—
Total losses for the period included in earnings	(3)		—		(8)		—
Purchases	—		—		—		(7)
Ending balance	$	(17)	$	(7)	$	(17)	$	(7)
Change in unrealized losses included in earnings for derivatives held as of June 30, 2020	$	(3)			$	(8)

Derivative Fair Value Measurements

The Company's contracts are non-exchange-traded and valued using prices provided by external sources. For some of the Company’s energy contracts, management receives quotes from multiple sources. To the extent that multiple quotes are received, the prices reflect the average of the bid-ask mid-point prices obtained from all sources believed to provide the most liquid market for the commodity. The remainder of the assets and liabilities represent contracts for which external sources or observable market quotes are not available. These contracts are valued based on various valuation techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of the observable market data with similar characteristics. As of June 30, 2020, contracts valued with prices provided by models and other valuation techniques make up 7% of derivative liabilities.

The Company’s significant position classified as Level 3 includes physical power executed in illiquid markets. The significant unobservable inputs used in developing fair value include illiquid power tenors and location pricing, which is derived by extrapolating pricing and as a basis to liquid locations. The tenor pricing and basis spread are based on observable market data when available or derived from historic prices and forward market prices from similar observable markets when not available.

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company's Level 3 positions as of June 30, 2020:

	June 30, 2020
	Fair Value						Input/Range
	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low	High	Weighted Average
(In millions)
Power Contracts	$	—	$	(17)	Discounted Cash Flow	Forward Market Price (per MWh)	8.71	40.55	16.07

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of June 30, 2020:

Significant Observable Input	Position	Change In Input	Impact on Fair Value Measurement
Forward Market Price Power	Buy	Increase/(Decrease)	Higher/(Lower)
Forward Market Price Power	Sell	Increase/(Decrease)	Lower/(Higher)

The fair value of each contract is discounted using a risk-free interest rate. In addition, a credit reserve is applied to reflect credit risk, which is, for interest rate swaps, calculated based on credit default swaps using the bilateral method. For commodities, to the extent that the net exposure under a specific master agreement is an asset, the Company uses the counterparty’s default swap rate. If the net exposure under a specific master agreement is a liability, the Company uses a proxy of its own default swap rate. For interest rate swaps and commodities, the credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of June 30, 2020, the non-performance reserve was a $13 million gain recorded primarily in interest expense in the consolidated statements of operations. It is possible that future market prices could vary from those used in recording assets and liabilities and such variations could be material.

Concentration of Credit Risk

In addition to the credit risk discussion in Note 2, Summary of Significant Accounting Policies, to the consolidated financial statements included in the Company's 2019 Form 10-K, the following is a discussion of the concentration of credit risk for the Company's financial instruments. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; (ii) monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties.

Counterparty credit exposure includes credit risk exposure under certain long-term agreements, including solar and other PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company estimates the exposure related to these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. The majority of these power contracts are with utilities with strong credit quality and public utility commission or other regulatory support. However, such regulated utility counterparties can be impacted by changes in government regulations or adverse financial conditions, which the Company is unable to predict.

On January 31, 2019, PG&E filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. On June 20, 2020, the Bankruptcy Court confirmed the PG&E Plan, which provided for PG&E to assume all of its PPAs with the Company. On July 1, 2020, PG&E emerged from bankruptcy. The Company had $5 million in accounts receivable due from PG&E for its consolidated projects that was previously recorded to non-current assets, and reclassified to current assets as of June 30, 2020, all of which was received in July of 2020.

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Derivative Instruments and Hedging Activities

6 Months Ended

Jun. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

This footnote should be read in conjunction with the complete description under Note 7, Accounting for Derivative Instruments and Hedging Activities, to the consolidated financial statements included in the Company's 2019 Form 10-K.

Interest Rate Swaps

The Company enters into interest rate swap agreements in order to hedge the variability of expected future cash interest payments. As of June 30, 2020, the Company had interest rate derivative instruments on non-recourse debt extending through 2043, a portion of which were designated as cash flow hedges. Under the interest rate swap agreements, the Company pays a fixed rate and the counterparties to the agreements pay a variable interest rate.

Energy-Related Commodities

As of June 30, 2020, the Company had energy-related derivative instruments extending through 2029. At June 30, 2020, these contracts were not designated as cash flow or fair value hedges.

Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy of the Company's open derivative transactions broken out by type:

		Total Volume
		June 30, 2020		December 31, 2019
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		2
Power	MWh	(2)		(2)
Interest	Dollars	$	1,965	$	1,788

Fair Value of Derivative Instruments

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

	Fair Value
		Derivative Liabilities
		June 30, 2020		December 31, 2019
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current		$	8	$	3
Interest rate contracts long-term		20		11
Total Derivatives Designated as Cash Flow Hedges		28		14
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current		32		13
Interest rate contracts long-term		155		56
Commodity contracts current		1		—
Commodity contracts long-term		17		9
Total Derivatives Not Designated as Cash Flow Hedges		205		78
Total Derivatives		$	233	$	92

The Company has elected to present derivative assets and liabilities on the balance sheet on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As of June 30, 2020 and December 31, 2019, there was no outstanding collateral paid or received. The following tables summarize the offsetting of derivatives by the counterparty master agreement level as of June 30, 2020 and December 31, 2019:

As of June 30, 2020	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Commodity contracts:	(In millions)
Derivative liabilities	$	(18)	$	1	$	(17)
Total commodity contracts	(18)		1		(17)
Interest rate contracts:
Derivative liabilities	(215)		(1)		(216)
Total interest rate contracts	(215)		(1)		(216)
Total derivative instruments	$	(233)	$	—	$	(233)

As of December 31, 2019	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Commodity contracts:	(In millions)
Derivative liabilities	$	(9)	$	(1)	$	(10)
Total commodity contracts	(9)		(1)		(10)
Interest rate contracts:
Derivative liabilities	(83)		1		(82)
Total interest rate contracts	(83)		1		(82)
Total derivative instruments	$	(92)	$	—	$	(92)

Accumulated Other Comprehensive Loss

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

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
	(In millions)
Accumulated OCL beginning balance	$	(43)	$	(40)	$	(31)	$	(38)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	1		14		3		17
Mark-to-market of cash flow hedge accounting contracts	3		(9)		(11)		(14)
Accumulated OCL ending balance, net of income tax benefit of $7, $6, $7 and $6, respectively	(39)		(35)		(39)		(35)
Accumulated OCL attributable to noncontrolling interests	(20)		(19)		(20)		(19)
Accumulated OCL attributable to Clearway Energy, Inc.	$	(19)	$	(16)	$	(19)	$	(16)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4	$	(10)			$	(10)

Impact of Derivative Instruments on the Statements of Operations

Gains and losses related to the Company's derivatives are recorded in the consolidated statements of operations as follows:

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
	(In millions)
Interest Rate Contracts (Interest Expense)	$	(13)	$	(36)	$	(92)	$	(54)
Mark-to-market economic hedging activities (a)	(3)		—		(8)		—

^(a) Relates to long-term power hedge at Elbow Creek Wind Project LLC, or Elbow Creek.

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

See Note 5, Fair Value of Financial Instruments, for a discussion regarding concentration of credit risk.

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Long-term Debt

6 Months Ended

Jun. 30, 2020

Debt Disclosure [Abstract]

Long-term Debt

Long-term Debt

This note should be read in conjunction with the complete description under Note 10, Long-term Debt, to the consolidated financial statements included in the Company's 2019 Form 10-K. Long-term debt consisted of the following:

	June 30, 2020		December 31, 2019		June 30, 2020, interest rate % (a)	Letters of Credit Outstanding at June 30, 2020
	(In millions, except rates)
2020 Convertible Notes (e)	$	—	$	45	3.250
2024 Senior Notes (b)	—		88		5.375
2025 Senior Notes	600		600		5.750
2026 Senior Notes	350		350		5.000
2028 Senior Notes	850		600		4.750
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (c)	—		—		L+2.00	56
Project-level debt:
Alpine, due 2022 (d)	117		119		L+2.00	8
Alta Wind I-V lease financing arrangements, due 2034 and 2035	816		844		5.696 - 7.015	29
Buckthorn Solar, due 2025	128		129		L+1.750	26
Carlsbad Holdco, due 2038	215		216		4.210	9
Carlsbad Energy Holdings LLC, due 2027 and 2038	582		582		various	81
Chestnut Borrower, LLC, due 2024	110		—		L+2.50	8
CS4 Borrower, due 2026	104		—		L+2.00	4
CVSR, due 2037 (d)	684		696		2.339 - 3.775	—
CVSR Holdco Notes, due 2037 (d)	176		182		4.680	13
Duquesne, due 2059	95		95		4.620	—
El Segundo Energy Center, due 2023	269		303		L+1.75 - L+2.375	138
Energy Center Minneapolis Series D, E, F, G, H Notes, due 2025-2037	327		328		various	—
Laredo Ridge, due 2028	81		84		L+2.125	10
Kansas South, due 2030 (d)	23		24		L+2.25	2
Kawailoa Solar Holdings LLC, due 2026	82		82		L+1.375	15
Marsh Landing, due 2023 (d)	190		206		L+2.125	27
Oahu Solar Holdings LLC, due 2026	91		91		L+1.375	17
Repowering Partnership Holdco LLC, due 2020 (b)	—		228		L+.85	—
South Trent, due 2028	40		43		L+1.350	12
Tapestry, due 2031	149		156		L+1.375	18
Utah Solar Portfolio, due 2022	247		254		L+2.625	13
Viento, due 2023	35		42		L+2.00	14
Walnut Creek, due 2023	161		175		L+1.75	92
Other	286		296		various	34
Subtotal project-level debt:	5,008		5,175
Total debt	6,808		6,858
Less current maturities	(357)		(1,824)
Less net debt issuance costs	(79)		(78)
Add premiums(f)	5		—
Total long-term debt	$	6,377	$	4,956

^(a) As of June 30, 2020, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023 and Kansas South, due 2030 where L+ equals 6 month LIBOR plus x% and Utah Solar Portfolio, where L+ equals 1 month LIBOR plus 2.625%

^(b) Repaid in the first quarter of 2020, as further described below

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

^(d) Entities affected by PG&E Bankruptcy, see further discussion below

^(e) Matured and repaid on June 1, 2020

^(f) Premiums relate to the 2028 Senior Notes

The financing arrangements listed above contain certain covenants, including financial covenants that the Company is required to be in compliance with during the term of the respective arrangement. As of June 30, 2020, the Company was in compliance with all of the required covenants, other than any covenants impacted by the PG&E Bankruptcy, as discussed below. The discussion below describes material changes to or additions of long-term debt for the six months ended June 30, 2020.

Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility

As of June 30, 2020, the Company had no outstanding borrowings under the revolving credit facility and $56 million in letters of credit outstanding. During the six months ended June 30, 2020, the Company borrowed $265 million under the revolving credit facility, and subsequently repaid $265 million utilizing the proceeds from the issuance of additional 2028 Senior Notes, as described below, and cash on hand.

2028 Senior Notes

On May 21, 2020, the Company completed the issuance of an additional $250 million in aggregate principal amount of its 4.750% Senior Notes due 2028. The 2028 Senior Notes bear interest at 4.75% and mature on March 15, 2028. Interest on the 2028 Senior Notes is payable semi-annually on March 15 and September 15 of each year, and interest payments will commence on September 15, 2020. The 2028 Senior Notes are unsecured obligations of Clearway Energy Operating, LLC and are guaranteed by Clearway Energy, LLC and by certain of Clearway Energy Operating LLC’s wholly owned current and future subsidiaries. The notes were issued at a price of 102% of par plus accrued interest from December 11, 2019. The net proceeds were utilized to repay the $45 million outstanding principal amount of the Company's 2020 Convertible Notes on June 1, 2020, as well as to repay amounts outstanding under the Company’s revolving credit facility and for general corporate purposes.

2024 Senior Notes Redemption

On January 3, 2020, the Company redeemed the $88 million aggregate principal amount of the 2024 Senior Notes that remained outstanding following the Company's tender offer for the 2024 Senior Notes in December 2019. The redemption was effectuated at a premium of 102.7% for a total consideration of $90 million and as a result, the Company recorded a loss on debt extinguishment in the amount of $3 million, which also included the write off of previously deferred financing fees related to the 2024 Senior Notes.

Project - level Debt

PG&E Bankruptcy

As of June 30, 2020, distributions from all PG&E affected projects to Clearway Energy Operating LLC were prohibited under the related debt agreements. On July 1, 2020, PG&E emerged from bankruptcy and assumed the Company's contracts without modification. In addition, PG&E paid to the Company's applicable projects the portion of the invoices corresponding to the electricity delivered between January 1 and January 28, 2019. These invoices related to the pre-petition period services and any payment therefore required the approval of the Bankruptcy Court. The Company has reclassified the related debt to non-current based on its original maturity as of June 30, 2020.

Repowering Partnership Holdco LLC, due 2020

In February 2020, the Company repaid $260 million of construction debt outstanding under the construction loan facility. The repayment was effectuated with the proceeds from the tax equity contributions for Wildorado TE Holdco, as further descried in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities as well as with the contributions by the Company.

Consolidation of DGPV Holdco 3

Upon consolidation of DGPV Holdco 3, as described in Note 4, Investments Accounted for by the Equity Method and Variable Interest Entities, the Company consolidates additional non-recourse debt for certain subsidiaries as further described below.

Renew CS4 Borrower LLC, or CS4 Borrower, a consolidated subsidiary of DGPV Holdco 3, is party to a credit agreement for construction loans up to $97.4 million, an investment tax credit bridge loan, or ITC bridge loan, for up to $89.9 million and letter of credit facilities up to $4.9 million. The construction loan and the ITC bridge loan both have an interest rate of LIBOR plus an applicable margin of 2.00% per annum. As of June 30, 2020, all construction loans were converted to term loans and the ITC bridge loans were repaid in connection with tax equity funding. The term loan bears annual interest at a rate of LIBOR plus an applicable margin, which is 2.00% per annum through the third anniversary of the

term conversion, and 2.25% per annum thereafter through the maturity date in June 2026. The borrowings are secured by the membership interests in the project companies.

Chestnut Borrower LLC, a consolidated subsidiary of DGPV Holdco 3, is party to a credit agreement for term loans of up to $120.3 million and letters of credit of up to $7.9 million. The loans bear annual interest at a rate of LIBOR plus an applicable margin, which is 2.50% per annum through the fifth anniversary of the financial closing date, or July 2022, and 2.75% per annum thereafter through the maturity date in April 2024. The borrowings are secured by the membership interests in the project companies.

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Earnings Per Share

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per Share

Basic earnings per common share is computed by dividing net income by the weighted average number of common shares outstanding. Shares issued during the year are weighted for the portion of the year that they were outstanding. Diluted earnings per share is computed in a manner consistent with that of basic earnings per share while giving effect to all potentially dilutive common shares that were outstanding during the period.

The reconciliation of Clearway Energy, Inc.'s basic and diluted earnings per share is shown in the following tables:

	Three months ended June 30,
	2020				2019
(In millions, except per share data) (a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$	14	$	33	$	(8)	$	(16)
Weighted average number of common shares outstanding — basic and diluted	35		80		35		73
Income (loss) per weighted average common share — basic and diluted	$	0.41	$	0.41	$	(0.22)	$	(0.22)

^(a) Basic and diluted earnings (losses) per share might not recalculate due to presenting values in millions rather than whole dollars.

	Six months ended June 30,
	2020				2019
(In millions, except per share data) (a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$	6	$	13	$	(14)	$	(30)
Weighted average number of common shares outstanding — basic and diluted	35		79		35		73
Income (loss) per weighted average common share — basic and diluted	$	0.16	$	0.16	$	(0.41)	$	(0.41)

^(a) Basic and diluted earnings (losses) per share might not recalculate due to presenting values in millions rather than whole dollars.

The following table summarizes the Company's outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted earnings per share, the 2020 Convertible Notes were repaid on June 1, 2020:

	Three months ended June 30,		Six months ended June 30,
		2019		2019
	(In millions of shares)
2020 Convertible Notes - Common Class C		2		2

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Changes in Capital Structure

6 Months Ended

Jun. 30, 2020

Equity [Abstract]

Changes in Capital Structure

Changes in Capital Structure

At-the-Market Equity Offering Program, or the ATM Program

Clearway Energy, Inc. is party to an equity distribution agreement with Barclays Capital Inc., Credit Suisse Securities (USA) LLC, J.P. Morgan Securities LLC and RBC Capital Markets, LLC, as sales agents. Pursuant to the terms of the equity distribution agreement, Clearway Energy, Inc. was able to offer and sell shares of its Class C common stock from time to time through the sales agents up to an aggregate sales price of $150 million through an at-the-market equity offering program, or the ATM Program. As of June 30, 2020, the Company had completed the issuance of shares of Class C common stock available under the ATM Program.

During the six months ended June 30, 2020, Clearway Energy, Inc. issued and sold 1,749,665 shares of Class C common stock for net proceeds of $38 million. The Company utilized the proceeds of the sales to acquire 1,749,665 Class C units of Clearway Energy LLC and, as a result, the Company currently owns 57.41% of the economic interests of Clearway Energy LLC, with CEG retaining 42.59% of the economic interests of Clearway Energy LLC.

Dividends to Class A and Class C common stockholders

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

Dividends on the Class A common stock and Class C common stock are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations. The Company expects that, based on current circumstances, comparable cash dividends will continue to be paid in the foreseeable future.

On July 30, 2020, the Company declared quarterly dividends on its Class A common stock and Class C common stock of $0.3125 per share payable on September 15, 2020, to stockholders of record as of September 1, 2020.

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

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Segment Reporting

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Segment Reporting

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

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	107	$	180	$	42	$	—	$	329
Cost of operations	22		39		26		—		87
Depreciation, amortization and accretion	33		59		7		—		99
General and administrative	—		1		2		9		12
Development costs	—		—		1		—		1
Operating income (loss)	52		81		6		(9)		130
Equity in earnings of unconsolidated affiliates	1		15		—		—		16
Gain on sale of unconsolidated affiliate	—		—		—		49		49
Interest expense	(22)		(42)		(5)		(24)		(93)
Income before income taxes	31		54		1		16		102
Income tax expense	—		—		—		26		26
Net Income (Loss)	$	31	$	54	$	1	$	(10)	$	76
Total Assets	$	2,674	$	6,290	$	613	$	159	$	9,736

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	84	$	153	$	47	$	—	$	284
Cost of operations	13		35		30		—		78
Depreciation, amortization and accretion	25		58		7		—		90
Impairment losses	—		—		19		—		19
General and administrative	—		—		—		7		7
Acquisition-related transaction and integration costs	—		—		—		1		1
Development costs	—		—		2		—		2
Operating income (loss)	46		60		(11)		(8)		87
Equity in earnings of unconsolidated affiliates	2		9		—		—		11
Other income, net	—		1		—		—		1
Loss on debt extinguishment	—		(1)		—		—		(1)
Interest expense	(16)		(89)		(4)		(21)		(130)
Income (loss) before income taxes	32		(20)		(15)		(29)		(32)
Income tax expense	—		—		—		4		4
Net Income (Loss)	$	32	$	(20)	$	(15)	$	(33)	$	(36)

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	210	$	287	$	90	$	—	$	587
Cost of operations	46		75		59		—		180
Depreciation, amortization and accretion	66		121		14		—		201
General and administrative	—		1		3		17		21
Acquisition-related transaction and integration costs	—		—		—		1		1
Development costs	—		—		2		—		2
Operating income (loss)	98		90		12		(18)		182
Equity in earnings (losses) of unconsolidated affiliates	3		—		—		—		3
Gain on sale of unconsolidated affiliate	—		—		—		49		49
Other income, net	—		1		1		—		2
Loss on debt extinguishment	—		—		—		(3)		(3)
Interest expense	(52)		(151)		(10)		(47)		(260)
Income (loss) before income taxes	49		(60)		3		(19)		(27)
Income tax expense	—		—		—		4		4
Net Income (Loss)	$	49	$	(60)	$	3	$	(23)	$	(31)

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	163	$	241	$	97	$	—	$	501
Cost of operations	30		67		63		—		160
Depreciation, amortization and accretion	50		113		13		—		176
Impairment losses	—		—		19		—		19
General and administrative	—		—		1		12		13
Acquisition-related transaction and integration costs	—		—		—		2		2
Development costs	—		—		3		—		3
Operating income (loss)	83		61		(2)		(14)		128
Equity in earnings of unconsolidated affiliates	4		10		—		—		14
Other income, net	1		2		—		1		4
Loss on debt extinguishment	—		(1)		—		—		(1)
Interest expense	(32)		(148)		(8)		(43)		(231)
Income (loss) before income taxes	56		(76)		(10)		(56)		(86)
Income tax benefit	—		—		—		(3)		(3)
Net Income (Loss)	$	56	$	(76)	$	(10)	$	(53)	$	(83)

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Income Taxes

6 Months Ended

Jun. 30, 2020

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

Effective Tax Rate

The income tax provision consisted of the following:

	Three months ended June 30,						Six months ended June 30,
	2020			2019			2020			2019
	(In millions, except percentages)
Income (loss) before income tax benefit	$	102		$	(32)		$	(27)		$	(86)
Income tax expense (benefit)	26			4			4			(3)
Effective income tax rate	25.5		%	(12.5)		%	(14.8)		%	3.5		%

For the three and six months ended June 30, 2020 and 2019 the overall effective tax rate was different than the statutory rate of 21% primarily due to taxable earnings and losses allocated to partners' interest in Clearway Energy LLC, which includes the effects of applying HLBV method of accounting for book purposes for certain partnerships.

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

On March 27, 2020 the Coronavirus Aid, Relief, and Economic Security (CARES) Act, or the Act, was signed into law, which includes modifications to the business interest expense disallowance and net operating loss provisions. While the Company expects to utilize previously disallowed interest expense during 2020 as a result of the modifications, the Company does not expect the Act to have a material impact on the consolidated financial statements. The Company will continue to assess the effects of the Act and ongoing government guidance related to COVID-19 that may be issued.

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Related Party Transactions

6 Months Ended

Jun. 30, 2020

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

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

O&M Services Agreements by and between the Company and Clearway Renewable Operation & Maintenance LLC

Various wholly-owned subsidiaries of the Company in the Renewables segment are party to services agreements with Clearway Renewable Operation & Maintenance LLC, or RENOM, a wholly-owned subsidiary of CEG, which provides operation and maintenance, or O&M, to these subsidiaries. The Company incurred total expenses for these services of $9 million and $18 million for each of the three and six months ended June 30, 2020, respectively. The Company incurred total expenses for these services of $7 million and $14 million for each of the three and six months ended June 30, 2019, respectively. There was a balance of $9 million and $7 million due to RENOM as of June 30, 2020 and December 31, 2019, respectively.

Administrative Services Agreements by and between the Company and CEG

Various wholly-owned subsidiaries of the Company are parties to administrative services agreements with Clearway Asset Services and Clearway Solar Asset Management, two wholly-owned subsidiaries of CEG, which provide various administrative services to the Company's subsidiaries. The Company incurred expenses under these agreements of $2 million and $4 million for each of the three and six months ended June 30, 2020, respectively. The Company incurred expenses under these agreements of $1 million and $3 million for each of the three and six months ended June 30, 2019, respectively.

CEG Master Services Agreements

The Company is a party to Master Services Agreements with CEG, or MSAs, pursuant to which CEG and certain of its affiliates or third party service providers provide certain services to the Company, including operational and administrative services, which include human resources, information systems, external affairs, accounting, procurement and risk management services, and the Company provides certain services to CEG, including accounting, internal audit, tax and treasury services, in exchange for the payment of fees in respect of such services. Amounts due to CEG or its subsidiaries related to these MSAs are recorded as accounts payable - affiliate and amounts due to the Company from CEG and subsidiaries are recorded as accounts receivable - affiliate on the Company's consolidated balance sheet. The Company incurred expenses of $0.6 million and

$1.2 million under these agreements for each of the three and six months ended June 30, 2020, respectively. The expenses under these agreements were immaterial to the Company's financials for each of the three and six months ended June 30, 2019.

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Contingencies

6 Months Ended

Jun. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Contingencies

Contingencies

This note should be read in conjunction with the complete description under Note 17, Commitments and Contingencies, to the Company's 2019 Form 10-K.

Contingencies

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

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

Nebraska Public Power District Litigation

On January 11, 2019, Nebraska Public Power District, or NPPD, sent written notice to certain of the Company’s subsidiaries which own the Laredo Ridge and Elkhorn Ridge wind projects alleging an event of default under each of the PPAs between NPPD and the projects. NPPD alleges that the Company moved forward with certain transactions without obtaining the consent of NPPD. NPPD threatened to terminate the applicable PPAs by February 11, 2019 if the alleged default was not cured. The Company filed a motion for a temporary restraining order and preliminary injunction in the U.S. District Court for the District of Nebraska relating to the Laredo Ridge project, and a similar motion in the District Court of Knox County, Nebraska for the Elkhorn Ridge project, to enjoin NPPD from taking any actions related to the PPAs. On February 19, 2019, the U.S. District Court in the Laredo Ridge matter approved a stipulation between the parties to provide for an injunction preventing NPPD from terminating the PPA pending disposition of the litigation. On February 26, 2019, the Knox County District Court approved a similar stipulation relating to the Elkhorn Ridge project. On April 13, 2020, the U.S. District Court granted the wind projects' motion for summary judgment and permanently enjoined NPPD from terminating the PPAs in reliance on the alleged events of default. The U.S. District Court decision was appealed by NPPD on May 11, 2020 and the case in the Knox County District Court remains pending, but has been stayed pending the outcome of the U.S. District Court case. The Company believes the allegations of NPPD are meritless and the Company is vigorously defending its rights under the PPAs.

Buckthorn Solar Litigation

On October 8, 2019, the City of Georgetown, Texas, or Georgetown, filed a petition in the District Court of Williamson County, Texas naming Buckthorn Westex, LLC, the Company’s subsidiary that owns the Buckthorn Westex solar project, as the defendant, alleging fraud by nondisclosure and breach of contract in connection with the project and the PPA, and seeking (i) rescission and/or cancellation of the PPA, (ii) declaratory judgment that the alleged breaches constitute an event of default under the PPA entitling Georgetown to terminate, and (iii) recovery of all damages, costs of court, and attorneys’ fees. On November 15, 2019, Buckthorn Westex filed an original answer and counterclaims (i) denying Georgetown’s claims, (ii) alleging Georgetown has breached its contracts with Buckthorn Westex by failing to pay amounts due, and (iii) seeking relief in the form of (x) declaratory judgment that Georgetown’s alleged failure to pay amounts due constitute breaches of and an event of default under the PPA and that Buckthorn did not commit any events of default under the PPA, (y) recovery of costs, expenses, interest, and attorneys’ fees, and (z) such other relief to which it is entitled at law or in equity. Buckthorn Westex believes the allegations of Georgetown are meritless, and Buckthorn Westex is vigorously defending its rights under the PPA.

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Leases

6 Months Ended

Jun. 30, 2020

Leases [Abstract]

Leases

Leases

Accounting for Leases

The Company evaluates each arrangement at inception to determine if it contains a lease. All of the Company’s leases are operating leases as of June 30, 2020.

Lessee

The Company records its operating lease liabilities at the present value at lease commencement date of the lease payments over the lease term. Lease payments include fixed payment amounts, as well as variable rate payments based on an index initially measured at lease commencement date. Variable payments, including payments based on future performance and based on index changes, are recorded as the expense is incurred. The Company determines the relevant lease term by evaluating whether renewal and termination options are reasonably to certain to be exercised. The Company uses its incremental borrowing rate to calculate the present value of the lease payments, based on information available at the lease commencement date.

The Company’s leases consist of land leases for numerous operating asset locations, real estate leases and equipment leases. The terms and conditions for these leases vary by the type of underlying asset.

Lease expense was comprised of the following:

	Three months ended June 30, 2020		Three months ended June 30, 2019		Six months ended June 30, 2020		Six months ended June 30, 2019
	(In millions)
Operating lease cost - Fixed	$	5	$	2	$	9	$	4
Operating lease cost - Variable	3		3		5		7
Total lease cost	$	8	$	5	$	14	$	11

The Company lease liabilities as of June 30, 2020 and December 31, 2019 comprised of the following:

	June 30, 2020			December 31, 2019
	(In millions, except term and rate)
ROU Assets - operating leases, net	$	257		$	223
Short-term lease liability - operating leases (a)	7			7
Long-term lease liability - operating leases	260			227
Total lease liability	$	267		$	234
Weighted average remaining lease term	24			25
Weighted average discount rate	4.3		%	4.4		%
	Six months ended June 30, 2020			Six months ended June 30, 2019
Cash paid for operating leases	$	10		$	7

^(a) Short-term lease liability balances are included within the accrued expenses and other current liabilities line item of the consolidated balance sheets as of June 30, 2020 and December 31, 2019.

Maturities of operating lease liabilities as of June 30, 2020 are as follows:

(In millions)
Remainder of 2020	$	8
2021	18
2022	18
2023	18
2024	18
Thereafter	359
Total lease payments	439
Less imputed interest	(172)
Total lease liability - operating leases	$	267

Oahu Solar Lease Agreements

The Oahu Solar projects are party to various land lease agreements with a wholly owned subsidiary of CEG. The projects are leasing the land for a period of 35 years, with the ability to renew the lease for two additional five year periods. The Company has a lease liability of $20 million and $21 million as of December 31, 2019 and a corresponding right-of-use asset of $18 million and $19 million related to leases as of June 30, 2020 and December 31, 2019, respectively.

Lessor

        The majority of the Company’s revenue is obtained through PPAs or other contractual agreements that are accounted for as leases. These leases are comprised of both fixed payments and variable payments contingent upon volumes or performance metrics. The terms of the leases are further described in Item 2 — MD&A, Introduction, Environmental, Regulatory of this Form 10-Q. Many of the leases have renewal options at the end of the lease term. Termination may be allowed under specific circumstances in the lease arrangements, such as under an event of default. All of the Company’s leases are operating leases. Certain of these leases have both lease and non-lease components, and the Company allocates the transaction price to the components based on standalone selling prices. As disclosed in Note 2, Summary of Significant Accounting Policies, the following amounts of energy and capacity revenue are related to the Company’s leases:

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	181	$	—	$	182
Capacity revenue	112		—		—		112
Operating revenue	$	113	$	181	$	—	$	294

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	3	$	296	$	1	$	300
Capacity revenue	219		—		—		219
Operating revenue	$	222	$	296	$	1	$	519

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	157	$	1	$	159
Capacity revenue	85		—		—		85
Operating revenue	$	86	$	157	$	1	$	244

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	2	$	256	$	1	$	259
Capacity revenue	164		—		—		164
Operating revenue	$	166	$	256	$	1	$	423

Minimum future rent payments under the operating leases for the remaining periods as of June 30, 2020

(In millions)
Remainder of 2020	$	297
2021	444
2022	450
2023	259
2024	106
Thereafter	1,605
Total lease payments	$	3,161

Property, plant and equipment, net related to the Company’s operating leases were as follows:

(In millions)	June 30, 2020		December 31, 2019
Property, plant and equipment	$	6,974	$	6,942
Accumulated depreciation	(1,769)		(1,649)
Net property, plant and equipment	$	5,205	$	5,293

Leases

Leases

Accounting for Leases

The Company evaluates each arrangement at inception to determine if it contains a lease. All of the Company’s leases are operating leases as of June 30, 2020.

Lessee

The Company records its operating lease liabilities at the present value at lease commencement date of the lease payments over the lease term. Lease payments include fixed payment amounts, as well as variable rate payments based on an index initially measured at lease commencement date. Variable payments, including payments based on future performance and based on index changes, are recorded as the expense is incurred. The Company determines the relevant lease term by evaluating whether renewal and termination options are reasonably to certain to be exercised. The Company uses its incremental borrowing rate to calculate the present value of the lease payments, based on information available at the lease commencement date.

The Company’s leases consist of land leases for numerous operating asset locations, real estate leases and equipment leases. The terms and conditions for these leases vary by the type of underlying asset.

Lease expense was comprised of the following:

	Three months ended June 30, 2020		Three months ended June 30, 2019		Six months ended June 30, 2020		Six months ended June 30, 2019
	(In millions)
Operating lease cost - Fixed	$	5	$	2	$	9	$	4
Operating lease cost - Variable	3		3		5		7
Total lease cost	$	8	$	5	$	14	$	11

The Company lease liabilities as of June 30, 2020 and December 31, 2019 comprised of the following:

	June 30, 2020			December 31, 2019
	(In millions, except term and rate)
ROU Assets - operating leases, net	$	257		$	223
Short-term lease liability - operating leases (a)	7			7
Long-term lease liability - operating leases	260			227
Total lease liability	$	267		$	234
Weighted average remaining lease term	24			25
Weighted average discount rate	4.3		%	4.4		%
	Six months ended June 30, 2020			Six months ended June 30, 2019
Cash paid for operating leases	$	10		$	7

^(a) Short-term lease liability balances are included within the accrued expenses and other current liabilities line item of the consolidated balance sheets as of June 30, 2020 and December 31, 2019.

Maturities of operating lease liabilities as of June 30, 2020 are as follows:

(In millions)
Remainder of 2020	$	8
2021	18
2022	18
2023	18
2024	18
Thereafter	359
Total lease payments	439
Less imputed interest	(172)
Total lease liability - operating leases	$	267

Oahu Solar Lease Agreements

The Oahu Solar projects are party to various land lease agreements with a wholly owned subsidiary of CEG. The projects are leasing the land for a period of 35 years, with the ability to renew the lease for two additional five year periods. The Company has a lease liability of $20 million and $21 million as of December 31, 2019 and a corresponding right-of-use asset of $18 million and $19 million related to leases as of June 30, 2020 and December 31, 2019, respectively.

Lessor

        The majority of the Company’s revenue is obtained through PPAs or other contractual agreements that are accounted for as leases. These leases are comprised of both fixed payments and variable payments contingent upon volumes or performance metrics. The terms of the leases are further described in Item 2 — MD&A, Introduction, Environmental, Regulatory of this Form 10-Q. Many of the leases have renewal options at the end of the lease term. Termination may be allowed under specific circumstances in the lease arrangements, such as under an event of default. All of the Company’s leases are operating leases. Certain of these leases have both lease and non-lease components, and the Company allocates the transaction price to the components based on standalone selling prices. As disclosed in Note 2, Summary of Significant Accounting Policies, the following amounts of energy and capacity revenue are related to the Company’s leases:

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	181	$	—	$	182
Capacity revenue	112		—		—		112
Operating revenue	$	113	$	181	$	—	$	294

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	3	$	296	$	1	$	300
Capacity revenue	219		—		—		219
Operating revenue	$	222	$	296	$	1	$	519

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	157	$	1	$	159
Capacity revenue	85		—		—		85
Operating revenue	$	86	$	157	$	1	$	244

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	2	$	256	$	1	$	259
Capacity revenue	164		—		—		164
Operating revenue	$	166	$	256	$	1	$	423

Minimum future rent payments under the operating leases for the remaining periods as of June 30, 2020

(In millions)
Remainder of 2020	$	297
2021	444
2022	450
2023	259
2024	106
Thereafter	1,605
Total lease payments	$	3,161

Property, plant and equipment, net related to the Company’s operating leases were as follows:

(In millions)	June 30, 2020		December 31, 2019
Property, plant and equipment	$	6,974	$	6,942
Accumulated depreciation	(1,769)		(1,649)
Net property, plant and equipment	$	5,205	$	5,293

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Asset Impairments	6 Months Ended
	Jun. 30, 2020
Goodwill and Intangible Assets Disclosure [Abstract]
Asset Impairments	Asset ImpairmentsDuring the three and six months and ended June 30, 2019, the Company recorded an impairment loss of $19 million related to a facility in the Thermal segment. The fair value of the facility was determined using an income approach by applying a discounted cash flow methodology to the long-term budgets for each respective plant. The income approach utilized estimates of discounted future cash flows, which were Level 3 fair value measurement and include key inputs, such as forecasted power prices, operations and maintenance expense, and discount rates. The Company measured the impairment loss as the difference between the carrying amount and the fair value of the assets.

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Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2020

Accounting Policies [Abstract]

Use of Estimates

Use of Estimates

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

Revenue Recognition

Revenue Recognition

Revenue from Contracts with Customers

The Company applies the guidance in ASC 606, Revenue from Contracts with Customers, or Topic 606, when recognizing revenue associated with its contracts with customers. The Company's policies with respect to its various revenue streams are detailed below. In general, the Company applies the invoicing practical expedient to recognize revenue for the revenue streams detailed below, except in circumstances where the invoiced amount does not represent the value transferred to the customer.

Thermal Revenues

Steam and chilled water revenue is recognized as the Company transfers the product to the customer, based on customer usage as determined by meter readings taken at month-end. Some locations read customer meters throughout the month and recognize estimated revenue for the period between meter read date and month-end. For thermal contracts, the Company’s performance obligation to deliver steam and chilled water is satisfied over time and revenue is recognized based on the invoiced amount. The Thermal Business subsidiaries collect, and remit state and local taxes associated with sales to their customers, as required by governmental authorities. These taxes are presented on a net basis in the income statement.

As contracts for steam and chilled water are long-term contracts, the Company has performance obligations under these contracts that have not yet been satisfied. These performance obligations have transaction prices that are both fixed and variable, and which vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the Company cannot accurately estimate the amount of its unsatisfied performance obligations as it will vary based on customer usage, which will depend on factors such as weather and customer activity.

Power Purchase Agreements

The majority of the Company’s revenues are obtained through PPAs or other contractual agreements. Energy, capacity and where applicable, renewable attributes, from the majority of the Company’s renewable energy assets and certain conventional energy plants is sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer. The majority of these PPAs are accounted for as leases. Previously ASC 840, and currently ASC 842, requires the minimum lease payments received to be amortized over the term of the lease and contingent rentals are recorded when the achievement of the contingency becomes probable. Management's judgment is required in determining the economic life of each generating facility, in evaluating whether certain lease provisions constitute minimum payments or represent contingent rent and other factors in determining whether a contract contains a lease and whether the lease is an operating lease or capital lease.

Renewable Energy Credits

Renewable energy credits, or RECs, are usually sold through long-term PPAs. Revenue from the sale of self-generated RECs is recognized when the related energy is generated and simultaneously delivered even in cases where there is a certification lag as it has been deemed to be perfunctory.

In a bundled contract to sell energy, capacity and/or self-generated RECs, all performance obligations are deemed to be delivered at the same time and hence, timing of recognition of revenue for all performance obligations is the same and occurs over time. In such cases, it is often unnecessary to allocate transaction price to multiple performance obligations.

Contract Amortization

Assets and liabilities recognized from power sales agreements assumed through acquisitions related to the sale of electric capacity and energy in future periods for which the fair value has been determined to be significantly less (more) than market are amortized to revenue over the term of each underlying contract based on actual generation and/or contracted volumes or on a straight-line basis, where applicable.

Recently Issued Accounting Standards Not Yet Adopted

Recently Issued Accounting Standards Adopted in 2020

In March 2020, the FASB issued ASU 2020-4, Facilitation of the Effects of Reference Rate Reform on Financial Reporting. The amendments provide for optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria is met. These amendments apply only to contracts that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. The guidance is effective for all entities as of March 12, 2020 through December 31, 2022. The Company intends to apply the amendments to all its eligible contract modifications where applicable.

Recently Issued Accounting Standards Not Yet Adopted

In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes. The amendments in this ASU simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740, Income Taxes. The amendments also improve consistent application of and simplify GAAP for other areas of Topic 740 by clarifying and amending existing guidance. The guidance is effective January 1, 2021, with early adoption permitted. The Company does not expect the effect of the new guidance to be material on its consolidated financial statements.

Reclassification

Reclassification

Certain prior year amounts have been reclassified for comparative purposes.

Segment Reporting

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

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Nature of Business (Tables)

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Company Structure

The following table represents the structure of the Company as of June 30, 2020:

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Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2020

Accounting Policies [Abstract]

Schedule of Cash and Cash Equivalents

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

	June 30, 2020		December 31, 2019
	(In millions)
Cash and cash equivalents	$	175	$	155
Restricted cash	241		262
Cash, cash equivalents and restricted cash shown in the statement of cash flows	$	416	$	417

Schedule of Accumulated Amortization and Depreciation

The following table presents the accumulated depreciation included in the property, plant and equipment, net, and accumulated amortization included in intangible assets, net, respectively, as of June 30, 2020 and December 31, 2019:

	June 30, 2020		December 31, 2019
	(In millions)
Property, Plant and Equipment Accumulated Depreciation	$	2,036	$	1,880
Intangible Assets Accumulated Amortization	439		394

Dividends Declared

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

Distributions Made to Limited Liability Company (LLC) Member, by Distribution

The following table lists distributions paid to CEG during the period ended June 30, 2020 on Clearway Energy LLC's Class B and D units:

	Second Quarter 2020		First Quarter 2020
Distributions per Class B Unit	$	0.21	$	0.21
Distributions per Class D Unit	$	0.21	$	0.21

Disaggregation of Revenue

The following tables represent the Company’s disaggregation of revenue from contracts with customers along with the reportable segment for each category for the three and six months ended June 30, 2020 and 2019 respectively:

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	1	$	195	$	22	$	218
Capacity revenue(a)	112		—		12		124
Contract amortization	(6)		(16)		—		(22)
Other revenue	—		4		8		12
Mark-to-market for economic hedges	—		(3)		—		(3)
Total operating revenue	107		180		42		329
Less: Mark-to-market for economic hedges	—		3		—		3
Less: Lease revenue	(113)		(181)		—		(294)
Less: Contract amortization	6		16		—		22
Total revenue from contracts with customers	$	—	$	18	$	42	$	60

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	181	$	—	$	182
Capacity revenue	112		—		—		112
Total	$	113	$	181	$	—	$	294

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	3	$	320	$	50	$	373
Capacity revenue(a)	219		—		26		245
Contract amortization	(12)		(31)		(1)		(44)
Other revenue	—		6		15		21
Mark-to-market for economic hedges	—		(8)		—		(8)
Total operating revenue	210		287		90		587
Less: Mark-to-market for economic hedges	—		8		—		8
Less: Lease revenue	(222)		(296)		(1)		(519)
Less: Contract amortization	12		31		1		44
Total revenue from contracts with customers	$	—	$	30	$	90	$	120

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	3	$	296	$	1	$	300
Capacity revenue	219		—		—		219
Total	$	222	$	296	$	1	$	519

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	1	$	166	$	26	$	193
Capacity revenue(a)	85		—		14		99
Contract amortization	(2)		(15)		—		(17)
Other revenue	—		2		7		9
Total operating revenue	84		153		47		284
Less: Lease revenue	(86)		(157)		(1)		(244)
Less: Contract amortization	2		15		—		17
Total revenue from contracts with customers	$	—	$	11	$	46	$	57

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	157	$	1	$	159
Capacity revenue	85		—		—		85
Total	$	86	$	157	$	1	$	244

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue(a)	$	2	$	274	$	58	$	334
Capacity revenue(a)	164		—		27		191
Contract amortization	(3)		(30)		(1)		(34)
Mark-to-market for economic hedges	—		(7)		—		(7)
Other revenue	—		4		13		17
Total operating revenue	163		241		97		501
Less: Mark-to-market for economic hedges	—		7		—		7
Less: Lease revenue	(166)		(256)		(1)		(423)
Less: Contract amortization	3		30		1		34
Total revenue from contracts with customers	$	—	$	22	$	97	$	119

^(a) The following amounts of energy and capacity revenue relate to leases and are accounted for under ASC 842:

(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	2	$	256	$	1	$	259
Capacity revenue	164		—		—		164
Total	$	166	$	256	$	1	$	423

Contract with Customer, Asset and Liability

The following table reflects the contract assets and liabilities included on the Company’s balance sheet as of June 30, 2020:

(In millions)
Accounts receivable, net - Contracts with customers	$	39
Accounts receivable, net - Leases	122
Total accounts receivable, net	$	161

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Investments Accounted for by the Equity Method and Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Variable Interest Entities

Summarized financial information for the Company's consolidated VIEs consisted of the following as of June 30, 2020:

(In millions)	Oahu Solar Partnership		Kawailoa Partnership		Elbow Creek TE Holdco		Wildorado TE Holdco		DGPV Holdco 3		Alta TE Holdco		Spring Canyon		Buckthorn Renewables LLC		Other (a)
Other current and non-current assets	$	26	$	23	$	10	$	19	$	63	$	61	$	3	$	3	$	5
Property, plant and equipment	183		144		104		249		330		369		84		211		8
Intangible assets	—		—		1		—		1		231		—		—		—
Total assets	209		167		115		268		394		661		87		214		13
Current and non-current liabilities	127		117		26		12		281		44		6		7		3
Total liabilities	127		117		26		12		281		44		6		7		3
Noncontrolling interest	30		40		75		109		6		44		35		66		—
Net assets less noncontrolling interests	$	52	$	10	$	14	$	147	$	107	$	573	$	46	$	141	$	10

^(a) Other is comprised of Crosswinds and Hardin projects.

The following table shows the balances that were consolidated effective on May 29, 2020:

(In millions)	May 29, 2020
Current assets	$	32
Property, plant and equipment	330
Intangible assets	1
Other non-current assets	37
Total assets	$	400
Debt	206
Other current and non-current liabilities	84
Total liabilities	$	290
Noncontrolling interests and redeemable noncontrolling interests	6
Net assets less noncontrolling interests	$	104

Equity Method Investments

The Company's maximum exposure to loss as of June 30, 2020 is limited to its equity investment in the unconsolidated entities, as further summarized in the table below:

Name	Economic Interest	Investment Balance
		(In millions)
Utah Solar Portfolio (a)	50%	$	276
Desert Sunlight (b)	25%	276
Agua Caliente Solar (b)	16%	99
GenConn	50%	92
DGPV Holdco 1 LLC (c)	95%	82
DGPV Holdco 2 LLC (c)	95%	63
San Juan Mesa	75%	45
Elkhorn Ridge	66.7%	42
Avenal (b)	50%	(4)
		$	971

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

^(b) Entities that have PPAs with PG&E. For further update on PG&E Bankruptcy see Note 1— Nature of Business.

^(c) Economic interest based on cash to be distributed. DGPV Holdco 1 LLC and DGPV Holdco 2 LLC, are tax equity structures and VIEs.

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

	Three months ended June 30,				Six months ended June 30,
(In millions)	2020		2019		2020		2019
Income Statement Data:
DGPV Holdco 3 (a)
Operating revenue	$	7	$	8	$	14	$	12
Operating income	4		4		6		5
Net income (loss)	4		9		(12)		9
RPV Holdco (b)
Operating revenue	2		3		6		7
Operating income	—		—		—		1
Net (loss) income	—		(2)		3		(3)
GenConn
Operating revenue	15		15		29		31
Operating income	7		7		13		14
Net income	4		5		8		9
Desert Sunlight
Operating revenue	59		57		95		92
Operating income	42		37		63		53
Net income	25		16		28		20
Other (c)
Operating revenue	81		79		136		131
Operating income	40		34		52		44
Net income	$	32	$	20	$	22	$	16

^(a) Year to date as of the reconsideration event on May 29, 2020.

^(b) Year to date as of the sale on May 14, 2020 as described in Note 3, Acquisition and Dispositions.

^(c) Includes Agua Caliente, DGPV Holdco 1, DGPV Holdco 2, Elkhorn Ridge, Utah Solar Portfolio and San Juan Mesa.

	As of June 30, 2020		As of December 31, 2019
Balance Sheet Data:	(In millions)
DGPV Holdco 3 (a)
Current assets	$	—	$	39
Non-current assets	—		371
Current liabilities	—		61
Non-current liabilities	—		216
Redeemable noncontrolling interest	—		(1)
RPV Holdco (a)
Current assets	—		2
Non-current assets	—		162
Current liabilities	—		1
Non-current liabilities	—		8
Redeemable noncontrolling interest	—		31
GenConn
Current assets	36		37
Non-current assets	352		342
Current liabilities	14		16
Non-current liabilities	190		176
Desert Sunlight
Current assets	261		209
Non-current assets	1,271		1,296
Current liabilities	545		545
Non-current liabilities	482		484
Other (b)
Current assets	275		220
Non-current assets	2,807		2,879
Current liabilities	71		785
Non-current liabilities	991		277

^(a) As of June 30, 2020, these are no longer equity method investments

^(b) Includes Agua Caliente, DGPV Holdco 1, DGPV Holdco 2, Elkhorn Ridge, Utah Solar Portfolio and San Juan Mesa.

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Fair Value of Financial Instruments (Tables)

6 Months Ended

Jun. 30, 2020

Fair Value Disclosures [Abstract]

Estimated Carrying Values and Fair Values

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

	As of June 30, 2020				As of December 31, 2019
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
(In millions)
Long-term debt, including current portion (a)	$	6,813	$	6,917	$	6,858	$	6,957

^(a) Excludes net debt issuance costs, which are recorded as a reduction to long-term debt on the Company's consolidated balance sheets.

Fair Value Option, Disclosures

The following table presents the level within the fair value hierarchy for long-term debt, including current portion as of June 30, 2020 and December 31, 2019:

	As of June 30, 2020				As of December 31, 2019
	Level 2		Level 3		Level 2		Level 3
	(In millions)
Long-term debt, including current portion	$	1,849	$	5,068	$	1,736	$	5,221

Schedule of Fair Value, Assets and Liabilities

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

	As of June 30, 2020				As of December 31, 2019
	Fair Value (a)				Fair Value (a)
(In millions)	Level 2		Level 3		Level 2		Level 3
Derivative liabilities:
Commodity contracts	$	1	$	17	$	—	$	9
Interest rate contracts	215		—		83		—
Total liabilities	$	216	$	17	$	83	$	9

^(a) There were no derivative assets classified as Level 1, Level 2 or Level 3 and no liabilities classified as Level 1 as of June 30, 2020 and as of December 31, 2019.

The following table reconciles the beginning and ending balances for instruments that are recognized at fair value in the condensed consolidated financial statements using significant unobservable inputs:

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
(In millions)	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)				Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
Beginning balance	$	(14)	$	(7)	$	(9)	$	—
Total losses for the period included in earnings	(3)		—		(8)		—
Purchases	—		—		—		(7)
Ending balance	$	(17)	$	(7)	$	(17)	$	(7)
Change in unrealized losses included in earnings for derivatives held as of June 30, 2020	$	(3)			$	(8)

Fair Value Measurement Inputs and Valuation Techniques

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company's Level 3 positions as of June 30, 2020:

	June 30, 2020
	Fair Value						Input/Range
	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low	High	Weighted Average
(In millions)
Power Contracts	$	—	$	(17)	Discounted Cash Flow	Forward Market Price (per MWh)	8.71	40.55	16.07

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of June 30, 2020:

Significant Observable Input	Position	Change In Input	Impact on Fair Value Measurement
Forward Market Price Power	Buy	Increase/(Decrease)	Higher/(Lower)
Forward Market Price Power	Sell	Increase/(Decrease)	Lower/(Higher)

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Derivative Instruments and Hedging Activities (Tables)

6 Months Ended

Jun. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Net notional volume buy/(sell) of NRG Yield's open derivative transactions broken out by commodity

The following table summarizes the net notional volume buy of the Company's open derivative transactions broken out by type:

		Total Volume
		June 30, 2020		December 31, 2019
Commodity	Units	(In millions)
Natural Gas	MMBtu	2		2
Power	MWh	(2)		(2)
Interest	Dollars	$	1,965	$	1,788

Fair value within the derivative instrument valuation on the balance sheets

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

	Fair Value
		Derivative Liabilities
		June 30, 2020		December 31, 2019
	(In millions)
Derivatives Designated as Cash Flow Hedges:
Interest rate contracts current		$	8	$	3
Interest rate contracts long-term		20		11
Total Derivatives Designated as Cash Flow Hedges		28		14
Derivatives Not Designated as Cash Flow Hedges:
Interest rate contracts current		32		13
Interest rate contracts long-term		155		56
Commodity contracts current		1		—
Commodity contracts long-term		17		9
Total Derivatives Not Designated as Cash Flow Hedges		205		78
Total Derivatives		$	233	$	92

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

The following tables summarize the offsetting of derivatives by the counterparty master agreement level as of June 30, 2020 and December 31, 2019:

As of June 30, 2020	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Commodity contracts:	(In millions)
Derivative liabilities	$	(18)	$	1	$	(17)
Total commodity contracts	(18)		1		(17)
Interest rate contracts:
Derivative liabilities	(215)		(1)		(216)
Total interest rate contracts	(215)		(1)		(216)
Total derivative instruments	$	(233)	$	—	$	(233)

As of December 31, 2019	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Net Amount
Commodity contracts:	(In millions)
Derivative liabilities	$	(9)	$	(1)	$	(10)
Total commodity contracts	(9)		(1)		(10)
Interest rate contracts:
Derivative liabilities	(83)		1		(82)
Total interest rate contracts	(83)		1		(82)
Total derivative instruments	$	(92)	$	—	$	(92)

Effects of NRG Yield's accumulated OCI balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax

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

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
	(In millions)
Accumulated OCL beginning balance	$	(43)	$	(40)	$	(31)	$	(38)
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	1		14		3		17
Mark-to-market of cash flow hedge accounting contracts	3		(9)		(11)		(14)
Accumulated OCL ending balance, net of income tax benefit of $7, $6, $7 and $6, respectively	(39)		(35)		(39)		(35)
Accumulated OCL attributable to noncontrolling interests	(20)		(19)		(20)		(19)
Accumulated OCL attributable to Clearway Energy, Inc.	$	(19)	$	(16)	$	(19)	$	(16)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4	$	(10)			$	(10)

Derivative gains and losses

Gains and losses related to the Company's derivatives are recorded in the consolidated statements of operations as follows:

	Three months ended June 30,				Six months ended June 30,
	2020		2019		2020		2019
	(In millions)
Interest Rate Contracts (Interest Expense)	$	(13)	$	(36)	$	(92)	$	(54)
Mark-to-market economic hedging activities (a)	(3)		—		(8)		—

^(a) Relates to long-term power hedge at Elbow Creek Wind Project LLC, or Elbow Creek.

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Long-term Debt (Tables)

6 Months Ended

Jun. 30, 2020

Debt Disclosure [Abstract]

Schedule of long-term debt

Long-term debt consisted of the following:

	June 30, 2020		December 31, 2019		June 30, 2020, interest rate % (a)	Letters of Credit Outstanding at June 30, 2020
	(In millions, except rates)
2020 Convertible Notes (e)	$	—	$	45	3.250
2024 Senior Notes (b)	—		88		5.375
2025 Senior Notes	600		600		5.750
2026 Senior Notes	350		350		5.000
2028 Senior Notes	850		600		4.750
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 (c)	—		—		L+2.00	56
Project-level debt:
Alpine, due 2022 (d)	117		119		L+2.00	8
Alta Wind I-V lease financing arrangements, due 2034 and 2035	816		844		5.696 - 7.015	29
Buckthorn Solar, due 2025	128		129		L+1.750	26
Carlsbad Holdco, due 2038	215		216		4.210	9
Carlsbad Energy Holdings LLC, due 2027 and 2038	582		582		various	81
Chestnut Borrower, LLC, due 2024	110		—		L+2.50	8
CS4 Borrower, due 2026	104		—		L+2.00	4
CVSR, due 2037 (d)	684		696		2.339 - 3.775	—
CVSR Holdco Notes, due 2037 (d)	176		182		4.680	13
Duquesne, due 2059	95		95		4.620	—
El Segundo Energy Center, due 2023	269		303		L+1.75 - L+2.375	138
Energy Center Minneapolis Series D, E, F, G, H Notes, due 2025-2037	327		328		various	—
Laredo Ridge, due 2028	81		84		L+2.125	10
Kansas South, due 2030 (d)	23		24		L+2.25	2
Kawailoa Solar Holdings LLC, due 2026	82		82		L+1.375	15
Marsh Landing, due 2023 (d)	190		206		L+2.125	27
Oahu Solar Holdings LLC, due 2026	91		91		L+1.375	17
Repowering Partnership Holdco LLC, due 2020 (b)	—		228		L+.85	—
South Trent, due 2028	40		43		L+1.350	12
Tapestry, due 2031	149		156		L+1.375	18
Utah Solar Portfolio, due 2022	247		254		L+2.625	13
Viento, due 2023	35		42		L+2.00	14
Walnut Creek, due 2023	161		175		L+1.75	92
Other	286		296		various	34
Subtotal project-level debt:	5,008		5,175
Total debt	6,808		6,858
Less current maturities	(357)		(1,824)
Less net debt issuance costs	(79)		(78)
Add premiums(f)	5		—
Total long-term debt	$	6,377	$	4,956

^(a) As of June 30, 2020, L+ equals 3 month LIBOR plus x%, except for Viento, due 2023 and Kansas South, due 2030 where L+ equals 6 month LIBOR plus x% and Utah Solar Portfolio, where L+ equals 1 month LIBOR plus 2.625%

^(b) Repaid in the first quarter of 2020, as further described below

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

^(d) Entities affected by PG&E Bankruptcy, see further discussion below

^(e) Matured and repaid on June 1, 2020

^(f) Premiums relate to the 2028 Senior Notes

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Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

The reconciliation of Clearway Energy, Inc.'s basic and diluted earnings per share is shown in the following tables:

	Three months ended June 30,
	2020				2019
(In millions, except per share data) (a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$	14	$	33	$	(8)	$	(16)
Weighted average number of common shares outstanding — basic and diluted	35		80		35		73
Income (loss) per weighted average common share — basic and diluted	$	0.41	$	0.41	$	(0.22)	$	(0.22)

^(a) Basic and diluted earnings (losses) per share might not recalculate due to presenting values in millions rather than whole dollars.

	Six months ended June 30,
	2020				2019
(In millions, except per share data) (a)	Common Class A		Common Class C		Common Class A		Common Class C
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$	6	$	13	$	(14)	$	(30)
Weighted average number of common shares outstanding — basic and diluted	35		79		35		73
Income (loss) per weighted average common share — basic and diluted	$	0.16	$	0.16	$	(0.41)	$	(0.41)

(a) Basic and diluted earnings (losses) per share might not recalculate due to presenting values in millions rather than whole dollars.

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

The following table summarizes the Company's outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted earnings per share, the 2020 Convertible Notes were repaid on June 1, 2020:

	Three months ended June 30,		Six months ended June 30,
		2019		2019
	(In millions of shares)
2020 Convertible Notes - Common Class C		2		2

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Changes in Capital Structure Stockholders' Equity (Tables)

6 Months Ended

Jun. 30, 2020

Equity [Abstract]

Dividends Declared

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

The following table lists the dividends paid on the Company's Class A common stock and Class C common stock during the six months ended June 30, 2020:

	Second Quarter 2020		First Quarter 2020
Dividends per Class A share	$	0.21	$	0.21
Dividends per Class C share	$	0.21	$	0.21

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Segment Reporting (Tables)

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	107	$	180	$	42	$	—	$	329
Cost of operations	22		39		26		—		87
Depreciation, amortization and accretion	33		59		7		—		99
General and administrative	—		1		2		9		12
Development costs	—		—		1		—		1
Operating income (loss)	52		81		6		(9)		130
Equity in earnings of unconsolidated affiliates	1		15		—		—		16
Gain on sale of unconsolidated affiliate	—		—		—		49		49
Interest expense	(22)		(42)		(5)		(24)		(93)
Income before income taxes	31		54		1		16		102
Income tax expense	—		—		—		26		26
Net Income (Loss)	$	31	$	54	$	1	$	(10)	$	76
Total Assets	$	2,674	$	6,290	$	613	$	159	$	9,736

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	84	$	153	$	47	$	—	$	284
Cost of operations	13		35		30		—		78
Depreciation, amortization and accretion	25		58		7		—		90
Impairment losses	—		—		19		—		19
General and administrative	—		—		—		7		7
Acquisition-related transaction and integration costs	—		—		—		1		1
Development costs	—		—		2		—		2
Operating income (loss)	46		60		(11)		(8)		87
Equity in earnings of unconsolidated affiliates	2		9		—		—		11
Other income, net	—		1		—		—		1
Loss on debt extinguishment	—		(1)		—		—		(1)
Interest expense	(16)		(89)		(4)		(21)		(130)
Income (loss) before income taxes	32		(20)		(15)		(29)		(32)
Income tax expense	—		—		—		4		4
Net Income (Loss)	$	32	$	(20)	$	(15)	$	(33)	$	(36)

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	210	$	287	$	90	$	—	$	587
Cost of operations	46		75		59		—		180
Depreciation, amortization and accretion	66		121		14		—		201
General and administrative	—		1		3		17		21
Acquisition-related transaction and integration costs	—		—		—		1		1
Development costs	—		—		2		—		2
Operating income (loss)	98		90		12		(18)		182
Equity in earnings (losses) of unconsolidated affiliates	3		—		—		—		3
Gain on sale of unconsolidated affiliate	—		—		—		49		49
Other income, net	—		1		1		—		2
Loss on debt extinguishment	—		—		—		(3)		(3)
Interest expense	(52)		(151)		(10)		(47)		(260)
Income (loss) before income taxes	49		(60)		3		(19)		(27)
Income tax expense	—		—		—		4		4
Net Income (Loss)	$	49	$	(60)	$	3	$	(23)	$	(31)

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Corporate		Total
Operating revenues	$	163	$	241	$	97	$	—	$	501
Cost of operations	30		67		63		—		160
Depreciation, amortization and accretion	50		113		13		—		176
Impairment losses	—		—		19		—		19
General and administrative	—		—		1		12		13
Acquisition-related transaction and integration costs	—		—		—		2		2
Development costs	—		—		3		—		3
Operating income (loss)	83		61		(2)		(14)		128
Equity in earnings of unconsolidated affiliates	4		10		—		—		14
Other income, net	1		2		—		1		4
Loss on debt extinguishment	—		(1)		—		—		(1)
Interest expense	(32)		(148)		(8)		(43)		(231)
Income (loss) before income taxes	56		(76)		(10)		(56)		(86)
Income tax benefit	—		—		—		(3)		(3)
Net Income (Loss)	$	56	$	(76)	$	(10)	$	(53)	$	(83)

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2020

Income Tax Disclosure [Abstract]

Reconciliation of the U.S. federal statutory rate to the Company's effective rate

The income tax provision consisted of the following:

	Three months ended June 30,						Six months ended June 30,
	2020			2019			2020			2019
	(In millions, except percentages)
Income (loss) before income tax benefit	$	102		$	(32)		$	(27)		$	(86)
Income tax expense (benefit)	26			4			4			(3)
Effective income tax rate	25.5		%	(12.5)		%	(14.8)		%	3.5		%

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Leases (Tables)

6 Months Ended

Jun. 30, 2020

Leases [Abstract]

Lease Cost

Lease expense was comprised of the following:

	Three months ended June 30, 2020		Three months ended June 30, 2019		Six months ended June 30, 2020		Six months ended June 30, 2019
	(In millions)
Operating lease cost - Fixed	$	5	$	2	$	9	$	4
Operating lease cost - Variable	3		3		5		7
Total lease cost	$	8	$	5	$	14	$	11

The Company lease liabilities as of June 30, 2020 and December 31, 2019 comprised of the following:

	June 30, 2020			December 31, 2019
	(In millions, except term and rate)
ROU Assets - operating leases, net	$	257		$	223
Short-term lease liability - operating leases (a)	7			7
Long-term lease liability - operating leases	260			227
Total lease liability	$	267		$	234
Weighted average remaining lease term	24			25
Weighted average discount rate	4.3		%	4.4		%
	Six months ended June 30, 2020			Six months ended June 30, 2019
Cash paid for operating leases	$	10		$	7

^(a) Short-term lease liability balances are included within the accrued expenses and other current liabilities line item of the consolidated balance sheets as of June 30, 2020 and December 31, 2019.

Maturities of Operating Lease Liabilities

Maturities of operating lease liabilities as of June 30, 2020 are as follows:

(In millions)
Remainder of 2020	$	8
2021	18
2022	18
2023	18
2024	18
Thereafter	359
Total lease payments	439
Less imputed interest	(172)
Total lease liability - operating leases	$	267

Revenue Related to Leases

	Three months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	181	$	—	$	182
Capacity revenue	112		—		—		112
Operating revenue	$	113	$	181	$	—	$	294

	Six months ended June 30, 2020
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	3	$	296	$	1	$	300
Capacity revenue	219		—		—		219
Operating revenue	$	222	$	296	$	1	$	519

	Three months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	1	$	157	$	1	$	159
Capacity revenue	85		—		—		85
Operating revenue	$	86	$	157	$	1	$	244

	Six months ended June 30, 2019
(In millions)	Conventional Generation		Renewables		Thermal		Total
Energy revenue	$	2	$	256	$	1	$	259
Capacity revenue	164		—		—		164
Operating revenue	$	166	$	256	$	1	$	423

Minimum Future Rent Payments under Operating Leases

Minimum future rent payments under the operating leases for the remaining periods as of June 30, 2020

(In millions)
Remainder of 2020	$	297
2021	444
2022	450
2023	259
2024	106
Thereafter	1,605
Total lease payments	$	3,161

Future Minimum Lease Commitments Under Operating Leases

Property, plant and equipment, net related to the Company’s operating leases were as follows:

(In millions)	June 30, 2020		December 31, 2019
Property, plant and equipment	$	6,974	$	6,942
Accumulated depreciation	(1,769)		(1,649)
Net property, plant and equipment	$	5,205	$	5,293

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Nature of Business (Details)	6 Months Ended
	Jun. 30, 2020 MW
Nature of Business [Line Items]
Weighted average remaining contract duration	13 years
Conventional Generation, Utility-Scale Solar, Distributed Solar, and Wind
Nature of Business [Line Items]
Power generation capacity, megawatts	5,991
Thermal
Nature of Business [Line Items]
Power generation capacity, megawatts	36
Steam and chilled water capacity, megawatts thermal equivalent	1,453
Clearway Energy LLC
Nature of Business [Line Items]
Ownership interest (as a percentage)	57.41%
CEG | Clearway Energy LLC
Nature of Business [Line Items]
Ownership interest (as a percentage)	42.59%
CEG | Clearway Energy, Inc.
Nature of Business [Line Items]
Ownership interest (as a percentage)	54.94%
Public Shareholders | Clearway Energy, Inc.
Nature of Business [Line Items]
Ownership interest (as a percentage)	45.06%

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Summary of Significant Accounting Policies - Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Millions	Jul. 31, 2020	Jun. 30, 2020	Dec. 31, 2019	Jun. 30, 2019	Dec. 31, 2018
Cash and Cash Equivalents [Line Items]
Cash and cash equivalents, held at project subsidiaries		$ 116	$ 125
Cash and cash equivalents		175	155
Restricted cash		241	262
Cash, cash equivalents and restricted cash shown in the statement of cash flows		416	$ 417	$ 296	$ 583
Subsequent Event | Subsidiary
Cash and Cash Equivalents [Line Items]
Cash distributions	$ 50
Long Term Debt Current
Cash and Cash Equivalents [Line Items]
Restricted cash		20
Debt Service Obligations
Cash and Cash Equivalents [Line Items]
Restricted cash		56
Cash Distribution
Cash and Cash Equivalents [Line Items]
Restricted cash		85
Subsidiaries Affected By Bankruptcy
Cash and Cash Equivalents [Line Items]
Restricted cash		14
Operating Funds
Cash and Cash Equivalents [Line Items]
Restricted cash		$ 80

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Summary of Significant Accounting Policies - Accumulated Depreciation, Accumulated Amortization (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Property, Plant and Equipment Accumulated Depreciation	$ 2,036	$ 1,880
Intangible Assets Accumulated Amortization	$ 439	$ 394

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Summary of Significant Accounting Policies - Dividends Paid (Details) - $ / shares					3 Months Ended			6 Months Ended
	Sep. 15, 2020	Sep. 01, 2020	Aug. 03, 2020	Jul. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Subsequent Event
Class of Stock [Line Items]
Dividends payable, date declared				Jul. 30, 2020
Common stock, dividends, per share, declared (in dollars per share)			$ 0.3125	$ 0.3125
Dividends payable, date to be paid	Sep. 15, 2020
Dividends payable, date of record		Sep. 01, 2020
Common Class A
Class of Stock [Line Items]
Common stock, dividends, per share, cash paid (in dollars per share)					$ 0.21	$ 0.21	$ 0.20	$ 0.42	$ 0.40
Common Class C
Class of Stock [Line Items]
Common stock, dividends, per share, cash paid (in dollars per share)					$ 0.21	$ 0.21	$ 0.20	$ 0.42	$ 0.40

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Summary of Significant Accounting Policies - Noncontrolling Interests (Details) - $ / shares					3 Months Ended
	Sep. 15, 2020	Sep. 01, 2020	Aug. 03, 2020	Jul. 30, 2020	Jun. 30, 2020	Mar. 31, 2020
Common Class B
Summary of Significant Accounting Policies [Line Items]
Distribution made to limited liability company (LLC) member, distributions paid, per unit (in dollars per share)					$ 0.21	$ 0.21
Common Class D
Summary of Significant Accounting Policies [Line Items]
Distribution made to limited liability company (LLC) member, distributions paid, per unit (in dollars per share)					$ 0.21	$ 0.21
Subsequent Event
Summary of Significant Accounting Policies [Line Items]
Dividends payable, date declared				Jul. 30, 2020
Common stock, dividends, per share, declared (in dollars per share)			$ 0.3125	$ 0.3125
Dividends payable, date to be paid	Sep. 15, 2020
Dividends payable, date of record		Sep. 01, 2020

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Summary of Significant Accounting Policies - Disaggregated Revenues (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 329	$ 284	$ 587	$ 501
Lease income		(244)	(519)	(423)
Conventional Generation
Disaggregation of Revenue [Line Items]
Lease income		(86)	(222)	(166)
Renewables
Disaggregation of Revenue [Line Items]
Lease income		(157)	(296)	(256)
Thermal
Disaggregation of Revenue [Line Items]
Lease income		(1)	(1)	(1)
Energy Revenue
Disaggregation of Revenue [Line Items]
Lease income		(159)	(300)	(259)
Energy Revenue | Conventional Generation
Disaggregation of Revenue [Line Items]
Lease income		(1)	(3)	(2)
Energy Revenue | Renewables
Disaggregation of Revenue [Line Items]
Lease income		(157)	(296)	(256)
Energy Revenue | Thermal
Disaggregation of Revenue [Line Items]
Lease income		(1)	(1)	(1)
Capacity Revenue
Disaggregation of Revenue [Line Items]
Lease income		(85)	(219)	(164)
Capacity Revenue | Conventional Generation
Disaggregation of Revenue [Line Items]
Lease income		(85)	(219)	(164)
Capacity Revenue | Renewables
Disaggregation of Revenue [Line Items]
Lease income		0	0	0
Capacity Revenue | Thermal
Disaggregation of Revenue [Line Items]
Lease income		0	0	0
Operating Segments
Disaggregation of Revenue [Line Items]
Total operating revenues	329	284	587	501
Contract amortization	22	17	44	34
Mark-to-market for economic hedges	(3)		(8)	(7)
Lease income	(294)	(244)	(519)	(423)
Total revenue from contracts with customers	60	57	120	119
Operating Segments | Conventional Generation
Disaggregation of Revenue [Line Items]
Total operating revenues	107	84	210	163
Contract amortization	6	2	12	3
Mark-to-market for economic hedges	0		0	0
Lease income	(113)	(86)	(222)	(166)
Total revenue from contracts with customers	0	0	0	0
Operating Segments | Renewables
Disaggregation of Revenue [Line Items]
Total operating revenues	180	153	287	241
Contract amortization	16	15	31	30
Mark-to-market for economic hedges	(3)		(8)	(7)
Lease income	(181)	(157)	(296)	(256)
Total revenue from contracts with customers	18	11	30	22
Operating Segments | Thermal
Disaggregation of Revenue [Line Items]
Total operating revenues	42	47	90	97
Contract amortization	0	0	1	1
Mark-to-market for economic hedges	0		0	0
Lease income	0	(1)	(1)	(1)
Total revenue from contracts with customers	42	46	90	97
Operating Segments | Energy Revenue
Disaggregation of Revenue [Line Items]
Total operating revenues	218	193	373	334
Lease income	(182)	(159)	(300)	(259)
Operating Segments | Energy Revenue | Conventional Generation
Disaggregation of Revenue [Line Items]
Total operating revenues	1	1	3	2
Lease income	(1)	(1)	(3)	(2)
Operating Segments | Energy Revenue | Renewables
Disaggregation of Revenue [Line Items]
Total operating revenues	195	166	320	274
Lease income	(181)	(157)	(296)	(256)
Operating Segments | Energy Revenue | Thermal
Disaggregation of Revenue [Line Items]
Total operating revenues	22	26	50	58
Lease income	0	(1)	(1)	(1)
Operating Segments | Capacity Revenue
Disaggregation of Revenue [Line Items]
Total operating revenues	124	99	245	191
Lease income	(112)	(85)	(219)	(164)
Operating Segments | Capacity Revenue | Conventional Generation
Disaggregation of Revenue [Line Items]
Total operating revenues	112	85	219	164
Lease income	(112)	(85)	(219)	(164)
Operating Segments | Capacity Revenue | Renewables
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0	0	0
Lease income	0	0	0	0
Operating Segments | Capacity Revenue | Thermal
Disaggregation of Revenue [Line Items]
Total operating revenues	12	14	26	27
Lease income	0	0	0	0
Operating Segments | Other revenue
Disaggregation of Revenue [Line Items]
Total operating revenues	12	9	21	17
Operating Segments | Other revenue | Conventional Generation
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0	0	0
Operating Segments | Other revenue | Renewables
Disaggregation of Revenue [Line Items]
Total operating revenues	4	2	6	4
Operating Segments | Other revenue | Thermal
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 8	$ 7	$ 15	$ 13

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Summary of Significant Accounting Policies - Contract Balances (Details) $ in Millions	Jun. 30, 2020 USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable, net	$ 161
Contracts with customers
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable, net	39
Leases
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable, net	$ 122

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Acquisitions and Dispositions (Details) $ in Millions	May 14, 2020 USD ($)	Mar. 03, 2020	May 01, 2019 USD ($) MW
RPV Holdco 1 LLC
Business Acquisition [Line Items]
Proceeds from sale of interests	$ 75
Gain on sale of investment	$ 49
Energy Center Dover
Business Acquisition [Line Items]
Sale of assets percentage ownership interest sold		100.00%
Duquesne University District Energy System
Business Acquisition [Line Items]
Power generation capacity, megawatts | MW			87
Power purchase agreement period			40 years
Business combination, consideration transferred			$ 107

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Investments Accounted for by the Equity Method and Variable Interest Entities - Consolidated Entities (Details) - USD ($) $ in Millions	Jun. 30, 2020	May 29, 2020	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	$ 2,826		$ 3,029
Property, plant and equipment	6,256		6,063
Intangible assets	1,393		1,428
Total Assets	9,736		9,700
Total Liabilities	7,504		$ 7,437
Oahu Solar Partnership
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	26
Property, plant and equipment	183
Intangible assets	0
Total Assets	209
Total Liabilities	127
Noncontrolling interest	30
Net assets less noncontrolling interests	52
Kawailoa Partnership
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	23
Property, plant and equipment	144
Intangible assets	0
Total Assets	167
Total Liabilities	117
Noncontrolling interest	40
Net assets less noncontrolling interests	10
Elbow Creek TE Holdco
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	10
Property, plant and equipment	104
Intangible assets	1
Total Assets	115
Total Liabilities	26
Noncontrolling interest	75
Net assets less noncontrolling interests	14
Wildorado TE Holdco
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	19
Property, plant and equipment	249
Intangible assets	0
Total Assets	268
Total Liabilities	12
Noncontrolling interest	109
Net assets less noncontrolling interests	147
DGPV Holdco 3
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	63
Property, plant and equipment	330	$ 330
Intangible assets	1	1
Total Assets	394	400
Total Liabilities	281	290
Noncontrolling interest	6	6
Net assets less noncontrolling interests	107	$ 104
Alta TE Holdco
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	61
Property, plant and equipment	369
Intangible assets	231
Total Assets	661
Total Liabilities	44
Noncontrolling interest	44
Net assets less noncontrolling interests	573
Spring Canyon
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	3
Property, plant and equipment	84
Intangible assets	0
Total Assets	87
Total Liabilities	6
Noncontrolling interest	35
Net assets less noncontrolling interests	46
Buckthorn Renewables LLC
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	3
Property, plant and equipment	211
Intangible assets	0
Total Assets	214
Total Liabilities	7
Noncontrolling interest	66
Net assets less noncontrolling interests	141
Other
Schedule of Equity Method Investments [Line Items]
Other current and non-current assets	5
Property, plant and equipment	8
Intangible assets	0
Total Assets	13
Total Liabilities	3
Noncontrolling interest	0
Net assets less noncontrolling interests	$ 10

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Investments Accounted for by the Equity Method and Variable Interest Entities - DGPV Holdco 3 LLC (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020 USD ($) MW	Jun. 30, 2019 USD ($)	May 29, 2020 USD ($)	Dec. 31, 2019 USD ($)
Schedule of Equity Method Investments [Line Items]
Removal of investment	$ (971)			$ (1,183)
Current assets	654			608
Property, plant and equipment	6,256			6,063
Intangible assets	1,393			1,428
Other non-current assets	110			103
Total Assets	9,736			9,700
Total Liabilities	7,504			$ 7,437
Investment of cash	$ 10	$ 9
DGPV Holdco 3
Schedule of Equity Method Investments [Line Items]
Power generation capacity, megawatts | MW	113
Weighted average remaining contract life	21 years
Allocations of taxable income after (as a percentage)			99.00%
Removal of investment			$ 155
Current assets			32
Property, plant and equipment	$ 330		330
Intangible assets	1		1
Other non-current assets			37
Total Assets	394		400
Debt			206
Other current and non-current liabilities			84
Total Liabilities	281		290
Noncontrolling interests and redeemable noncontrolling interests	6		6
Net assets less noncontrolling interests	107		$ 104
Investment of cash	$ 10

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Investments Accounted for by the Equity Method and Variable Interest Entities - Repowering Partnership II LLC (Details) - USD ($) $ in Millions		2 Months Ended	3 Months Ended			6 Months Ended
	May 11, 2020	Mar. 31, 2020	Jun. 30, 2020	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019	Feb. 07, 2020
Schedule of Equity Method Investments [Line Items]
Removal of related noncontrolling interest balance	$ 8				$ 19
Allocations of taxable income (as a percentage)								99.00%
Loss attributable to noncontrolling interests			$ 29	$ (12)		$ (49)	$ (39)
Wildorado TE Holdco
Schedule of Equity Method Investments [Line Items]
Business combination, consideration transferred		$ 112
Allocations of taxable income after (as a percentage)								5.00%
Wildorado TE Holdco | Repowering Partnership II LLC
Schedule of Equity Method Investments [Line Items]
Loss attributable to noncontrolling interests			$ (8)			$ (36)
Wind TE Holdco LLC | Repowering Partnership II LLC
Schedule of Equity Method Investments [Line Items]
Allocations of taxable income after (as a percentage)			60.14%			60.14%
CWSP Wildorado Elbow Holding LLC | Repowering Partnership II LLC
Schedule of Equity Method Investments [Line Items]
Allocations of taxable income after (as a percentage)			39.86%			39.86%
Repowering Partnership II LLC
Schedule of Equity Method Investments [Line Items]
Cash consideration	$ 70
Elbow Creek TE Holdco | Repowering Partnership II LLC
Schedule of Equity Method Investments [Line Items]
Loss attributable to noncontrolling interests			$ (6)			$ (8)
Third Party Investor | Wildorado TE Holdco | Capital Unit, Class A
Schedule of Equity Method Investments [Line Items]
Business acquisition, percentage of voting interests acquired								100.00%
Acquired membership interests								$ 148

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Investments Accounted for by the Equity Method and Variable Interest Entities - Unconsolidated Entities (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Equity investments in affiliates	$ 971				$ 971		$ 1,183
Operating revenues	329		$ 284		587	$ 501
Operating income	130		87		182	128
Net income (loss)	76	$ (107)	(36)	$ (47)	(31)	(83)
Current assets	654				654		608
Current liabilities	555				555		2,057
Non-current liabilities	$ 6,949				$ 6,949		5,380
Utah Solar Portfolio
Schedule of Equity Method Investments [Line Items]
Economic Interest	50.00%				50.00%
Equity investments in affiliates	$ 276				$ 276
Desert Sunlight
Schedule of Equity Method Investments [Line Items]
Economic Interest	25.00%				25.00%
Equity investments in affiliates	$ 276				$ 276
Operating revenues	59		57		95	92
Operating income	42		37		63	53
Net income (loss)	25		16		28	20
Current assets	261				261		209
Non-current assets	1,271				1,271		1,296
Current liabilities	545				545		545
Non-current liabilities	$ 482				$ 482		484
Agua Caliente Solar
Schedule of Equity Method Investments [Line Items]
Economic Interest	16.00%				16.00%
Equity investments in affiliates	$ 99				$ 99
GenConn
Schedule of Equity Method Investments [Line Items]
Economic Interest	50.00%				50.00%
Equity investments in affiliates	$ 92				$ 92
Operating revenues	15		15		29	31
Operating income	7		7		13	14
Net income (loss)	4		5		8	9
Current assets	36				36		37
Non-current assets	352				352		342
Current liabilities	14				14		16
Non-current liabilities	$ 190				$ 190		176
DGPV Holdco 1 LLC
Schedule of Equity Method Investments [Line Items]
Economic Interest	95.00%				95.00%
Equity investments in affiliates	$ 82				$ 82
DGPV Holdco 2 LLC
Schedule of Equity Method Investments [Line Items]
Economic Interest	95.00%				95.00%
Equity investments in affiliates	$ 63				$ 63
San Juan Mesa
Schedule of Equity Method Investments [Line Items]
Economic Interest	75.00%				75.00%
Equity investments in affiliates	$ 45				$ 45
Elkhorn Ridge
Schedule of Equity Method Investments [Line Items]
Economic Interest	66.70%				66.70%
Equity investments in affiliates	$ 42				$ 42
Avenal
Schedule of Equity Method Investments [Line Items]
Economic Interest	50.00%				50.00%
Equity investments in affiliates	$ (4)				$ (4)
DGPV Holdco 3
Schedule of Equity Method Investments [Line Items]
Operating revenues	7		8		14	12
Operating income	4		4		6	5
Net income (loss)	4		9		(12)	9
Current assets	0				0		39
Non-current assets	0				0		371
Current liabilities	0				0		61
Non-current liabilities	0				0		216
Redeemable noncontrolling interest	0				0		(1)
RPV Holdco
Schedule of Equity Method Investments [Line Items]
Operating revenues	2		3		6	7
Operating income	0		0		0	1
Net income (loss)	0		(2)		3	(3)
Current assets	0				0		2
Non-current assets	0				0		162
Current liabilities	0				0		1
Non-current liabilities	0				0		8
Redeemable noncontrolling interest	0				0		31
Other
Schedule of Equity Method Investments [Line Items]
Operating revenues	81		79		136	131
Operating income	40		34		52	44
Net income (loss)	32		$ 20		22	$ 16
Current assets	275				275		220
Non-current assets	2,807				2,807		2,879
Current liabilities	71				71		785
Non-current liabilities	$ 991				$ 991		$ 277

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Fair Value of Financial Instruments - Balance Sheet Grouping (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current portion of long-term debt — affiliate	$ 6,813	$ 6,858
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current portion of long-term debt — affiliate	6,917	6,957
Level 2 | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current portion of long-term debt — affiliate	1,849	1,736
Level 3 | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current portion of long-term debt — affiliate	$ 5,068	$ 5,221

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Fair Value of Financial Instruments - Recurring Fair Value (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	$ 233				$ 233		$ 92
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Change in unrealized losses included in earnings for derivatives held as of June 30, 2020	4	$ (12)	$ 5	$ (2)
Fair Value, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	216				216		83
Fair Value, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	17				17		9
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	(14)	(9)	(7)	0	(9)	$ 0
Total losses for the period included in earnings	(3)		0		(8)	0
Purchases	0		0		0	(7)
Ending balance	(17)	$ (14)	(7)	$ (7)	(17)	(7)
Change in unrealized losses included in earnings for derivatives held as of June 30, 2020	(3)				(8)
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	18				18		9
Commodity contracts | Fair Value, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	1				1		0
Commodity contracts | Fair Value, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	17				17		9
Interest rate contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	215				215		83
Interest rate contracts | Fair Value, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	215				215		83
Interest rate contracts | Fair Value, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability, fair value, gross liability	$ 0				$ 0		$ 0

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Fair Value of Financial Instruments - Narrative (Details) $ in Millions	Jun. 30, 2020 USD ($)
Fair Value Disclosures [Abstract]
Percent of derivative liabilities using level 3 fair value inputs	7.00%
Fair value assets, measured on recurring basis, valuation techniques, impact of credit reserve to fair value	$ 13
Accounts receivable, related parties	$ 5

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Fair Value of Financial Instruments - Significant Unobservable Inputs (Details) - Fair Value, Recurring - Energy Related Derivative - Level 3 $ in Millions	Jun. 30, 2020 USD ($) $ / MWh
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Derivative asset | $	$ 0
Derivative liability | $	$ 17
Low | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Derivative liability measurement input	8.71
High | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Derivative liability measurement input	40.55
Weighted Average | Measurement Input, Commodity Forward Price | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Derivative liability measurement input	16.07

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Derivative Instruments and Hedging Activities - Volumetric Underlying Derivative Transactions (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020 USD ($) MMBTU MWh	Jun. 30, 2019 USD ($) MMBTU MWh
Natural Gas | Long
Derivatives, Fair Value [Line Items]
Derivative nonmonetary notional amount (energy measure) | MMBTU	2	2
Power | Short
Derivatives, Fair Value [Line Items]
Derivative nonmonetary notional amount (energy measure) | MWh	2	2
Interest | Long
Derivatives, Fair Value [Line Items]
Derivative, notional amount | $	$ 1,965	$ 1,788

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Derivative Instruments and Hedging Activities - FV of Derivatives (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	$ (233)	$ (92)
Fair Value of gross derivative assets/(liabilities), net	(233)	(92)
Derivative asset fair value gross liability net of derivative liability fair value gross asset	0	0
Derivative asset, fair value, amount offset against collateral net of derivative liability, fair value, amount offset against collateral	(233)	(92)
Derivatives Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(28)	(14)
Derivatives Not Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(205)	(78)
Interest rate contracts current | Derivatives Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(8)	(3)
Interest rate contracts current | Derivatives Not Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(32)	(13)
Interest rate contracts long-term | Derivatives Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(20)	(11)
Interest rate contracts long-term | Derivatives Not Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(155)	(56)
Commodity contracts current | Derivatives Not Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(1)	0
Commodity contracts
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(18)	(9)
Derivative liability, fair value, gross asset	1	(1)
Derivative liability	(17)	(10)
Fair Value of gross derivative assets/(liabilities), net	(18)	(9)
Derivative asset fair value gross liability net of derivative liability fair value gross asset	1	(1)
Derivative asset, fair value, amount offset against collateral net of derivative liability, fair value, amount offset against collateral	(17)	(10)
Interest rate contracts
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	(215)	(83)
Derivative liability, fair value, gross asset	(1)	1
Derivative liability	(216)	(82)
Fair Value of gross derivative assets/(liabilities), net	(215)	(83)
Derivative asset fair value gross liability net of derivative liability fair value gross asset	(1)	1
Derivative asset, fair value, amount offset against collateral net of derivative liability, fair value, amount offset against collateral	(216)	(82)
Commodity contracts long-term | Derivatives Not Designated as Cash Flow Hedges:
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross	$ (17)	$ (9)

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Derivative Instruments and Hedging Activities - Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	$ 2,264	$ 2,145	$ 2,263	$ 2,224
Mark-to-market of cash flow hedge accounting contracts	4	5	(8)	3
Balance at end of period	2,232	2,054	2,232	2,054
Accumulated OCL ending balance, income tax benefit	7	6	7	6
Accumulated other comprehensive loss	(19)		(19)		$ (15)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4	(10)		(10)
Losses expected to be realized from OCL during the next 12 months, tax expense (benefit)	4		4
AOCI Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	(43)	(40)	(31)	(38)
Balance at end of period	(39)	(35)	(39)	(35)
Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	1	14	3	17
Mark-to-market of cash flow hedge accounting contracts	3	(9)	(11)	(14)
Accumulated Other Comprehensive Loss
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	(21)	(19)	(15)	(18)
Balance at end of period	(19)	(16)	(19)	(16)
Accumulated other comprehensive loss	(19)	(16)	(19)	(16)
AOCI Attributable to Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated other comprehensive loss	(20)	(19)	(20)	(19)
Noncontrolling Interest
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period	463	373	413	402
Balance at end of period	$ 370	$ 322	$ 370	$ 322

XML

Derivative Instruments and Hedging Activities Derivative Instruments and Hedging Activities - Impact to Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives	$ 4	$ (12)	$ 5	$ (2)
Interest rate contracts | Interest Expense
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives	(13)		(36)		$ (92)	$ (54)
Energy Related Derivative
Derivative Instruments, Gain (Loss) [Line Items]
Loss on derivatives	$ (3)		$ 0		$ (8)	$ 0

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Long-term Debt - Debt Table (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term debt	$ 6,808	$ 6,858
Current portion of long-term debt	(357)	(1,824)
Debt issuance costs, net	(79)	(78)
Add premiums	5	0
Long-term debt, excluding current maturities	6,377	4,956
2020 Convertible Notes
Debt Instrument [Line Items]
Long-term debt	$ 0	45
Debt instrument, interest rate, stated percentage	3.25%
2024 Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 0	88
Debt instrument, interest rate, stated percentage	5.375%
2025 Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 600	600
Debt instrument, interest rate, stated percentage	5.75%
2026 Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 350	350
Debt instrument, interest rate, stated percentage	5.00%
2028 Senior Notes
Debt Instrument [Line Items]
Long-term debt	$ 850	600
Debt instrument, interest rate, stated percentage	4.75%
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.00%
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 | Letter of Credit
Debt Instrument [Line Items]
Long-term debt	$ 0	0
Letters of credit outstanding, amount	56
Subtotal project-level debt:
Debt Instrument [Line Items]
Long-term debt	5,008	5,175
Alpine, due 2022
Debt Instrument [Line Items]
Long-term debt	$ 117	119
Alpine, due 2022 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.00%
Alpine, due 2022 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 8
Alta Wind I-V lease financing arrangements, due 2034 and 2035
Debt Instrument [Line Items]
Long-term debt	$ 816	844
Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Minimum
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	5.696%
Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Maximum
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	7.015%
Alta Wind I-V lease financing arrangements, due 2034 and 2035 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 29
Buckthorn Solar, due 2025
Debt Instrument [Line Items]
Long-term debt	$ 128	129
Buckthorn Solar, due 2025 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.75%
Buckthorn Solar, due 2025 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 26
Carlsbad Holdco, due 2038
Debt Instrument [Line Items]
Long-term debt	$ 215	216
Debt instrument, interest rate, stated percentage	4.21%
Carlsbad Holdco, due 2038 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 9
Carlsbad Energy Holdings LLC, due 2027 and 2038
Debt Instrument [Line Items]
Long-term debt	582	582
Carlsbad Energy Holdings LLC, due 2027 and 2038 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	81
Chestnut Borrower, LLC, due 2024
Debt Instrument [Line Items]
Long-term debt	$ 110	0
Chestnut Borrower, LLC, due 2024 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.50%
Chestnut Borrower, LLC, due 2024 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 8
CS4 Borrower, due 2026
Debt Instrument [Line Items]
Long-term debt	$ 104	0
CS4 Borrower, due 2026 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.00%
CS4 Borrower, due 2026 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 4
CVSR, due 2037
Debt Instrument [Line Items]
Long-term debt	$ 684	696
CVSR, due 2037 | Minimum
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	2.339%
CVSR, due 2037 | Maximum
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	3.775%
CVSR, due 2037 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 0
CVSR Holdco Notes, due 2037
Debt Instrument [Line Items]
Long-term debt	$ 176	182
Debt instrument, interest rate, stated percentage	4.68%
CVSR Holdco Notes, due 2037 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 13
Duquesne, due 2059
Debt Instrument [Line Items]
Long-term debt	$ 95	95
Debt instrument, interest rate, stated percentage	4.62%
Duquesne, due 2059 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 0
El Segundo Energy Center, due 2023
Debt Instrument [Line Items]
Long-term debt	$ 269	303
El Segundo Energy Center, due 2023 | Minimum | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.75%
El Segundo Energy Center, due 2023 | Maximum | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.375%
El Segundo Energy Center, due 2023 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 138
Energy Center Minneapolis Series D, E, F, G, H Notes, due 2025-2037
Debt Instrument [Line Items]
Long-term debt	327	328
Energy Center Minneapolis Series D, E, F, G, H Notes, due 2025-2037 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	0
Laredo Ridge, due 2028
Debt Instrument [Line Items]
Long-term debt	$ 81	84
Laredo Ridge, due 2028 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.125%
Laredo Ridge, due 2028 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 10
Kansas South, due 2030
Debt Instrument [Line Items]
Long-term debt	$ 23	24
Kansas South, due 2030 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.25%
Kansas South, due 2030 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 2
Kawailoa Solar Holdings LLC, due 2026
Debt Instrument [Line Items]
Long-term debt	$ 82	82
Kawailoa Solar Holdings LLC, due 2026 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.375%
Kawailoa Solar Holdings LLC, due 2026 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 15
Marsh Landing, due 2023
Debt Instrument [Line Items]
Long-term debt	$ 190	206
Marsh Landing, due 2023 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.125%
Marsh Landing, due 2023 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 27
Oahu Solar Holdings LLC, due 2026
Debt Instrument [Line Items]
Long-term debt	$ 91	91
Oahu Solar Holdings LLC, due 2026 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.375%
Oahu Solar Holdings LLC, due 2026 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 17
Repowering Partnership Holdco LLC, due 2020
Debt Instrument [Line Items]
Long-term debt	$ 0	228
Repowering Partnership Holdco LLC, due 2020 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	0.85%
Repowering Partnership Holdco LLC, due 2020 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 0
South Trent, due 2028
Debt Instrument [Line Items]
Long-term debt	$ 40	43
South Trent, due 2028 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.35%
South Trent, due 2028 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 12
Tapestry, due 2031
Debt Instrument [Line Items]
Long-term debt	$ 149	156
Tapestry, due 2031 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.375%
Tapestry, due 2031 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 18
Utah Solar Portfolio, due 2022
Debt Instrument [Line Items]
Long-term debt	$ 247	254
Utah Solar Portfolio, due 2022 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.625%
Utah Solar Portfolio, due 2022 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 13
Viento, due 2023
Debt Instrument [Line Items]
Long-term debt	$ 35	42
Viento, due 2023 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.00%
Viento, due 2023 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 14
Walnut Creek, due 2023
Debt Instrument [Line Items]
Long-term debt	$ 161	175
Walnut Creek, due 2023 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.75%
Walnut Creek, due 2023 | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 92
Other
Debt Instrument [Line Items]
Long-term debt	286	$ 296
Other | Letter of Credit
Debt Instrument [Line Items]
Letters of credit outstanding, amount	$ 34

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Long-term Debt - Debt Disclosures (Details) - USD ($) $ in Millions				1 Months Ended	3 Months Ended		6 Months Ended
	Jun. 01, 2020	May 21, 2020	Jan. 03, 2020	Feb. 29, 2020	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term debt					$ 6,808.0		$ 6,808.0		$ 6,858.0
Proceeds from the revolving credit facility							265.0	$ 22.0
Payments for the revolving credit facility							265.0	22.0
Loss on debt extinguishment					0.0	$ 1.0	3.0	$ 1.0
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023
Debt Instrument [Line Items]
Proceeds from the revolving credit facility							265.0
Payments for the revolving credit facility							$ 265.0
Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate							2.00%
2024 Senior Notes
Debt Instrument [Line Items]
Long-term debt					$ 0.0		$ 0.0		88.0
Debt instrument, interest rate, stated percentage					5.375%		5.375%
Construction Debt
Debt Instrument [Line Items]
Repayments of debt				$ 260.0
CS4 Borrower, due 2026
Debt Instrument [Line Items]
Long-term debt					$ 104.0		$ 104.0		0.0
CS4 Borrower, due 2026 | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate							2.00%
CS4 Borrower, due 2026 | London Interbank Offered Rate (LIBOR) | Renew CS4 Borrower LLC
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate					2.00%
CS4 Borrower, due 2026 | Conversion period one | Renew CS4 Borrower LLC
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					2.00%		2.00%
CS4 Borrower, due 2026 | Conversion period two | Renew CS4 Borrower LLC
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage					2.25%		2.25%
Letter of Credit | Clearway Energy LLC and Clearway Energy Operating LLC Revolving Credit Facility, due 2023
Debt Instrument [Line Items]
Long-term debt					$ 0.0		$ 0.0		$ 0.0
Letters of credit outstanding, amount					56.0		56.0
Letter of Credit | CS4 Borrower, due 2026
Debt Instrument [Line Items]
Letters of credit outstanding, amount					4.0		4.0
Letter of Credit | CS4 Borrower, due 2026 | Renew CS4 Borrower LLC
Debt Instrument [Line Items]
Debt amount (up to)					4.9		4.9
Letter of Credit | Chestnut Borrower credit agreement | Chestnut Borrower, LLC, due 2024
Debt Instrument [Line Items]
Debt amount (up to)					7.9		7.9
Construction loans | CS4 Borrower, due 2026 | Renew CS4 Borrower LLC
Debt Instrument [Line Items]
Debt amount (up to)					97.4		97.4
ITC bridge loan | CS4 Borrower, due 2026 | Renew CS4 Borrower LLC
Debt Instrument [Line Items]
Debt amount (up to)					89.9		89.9
Term loan | Chestnut Borrower credit agreement | Chestnut Borrower, LLC, due 2024
Debt Instrument [Line Items]
Debt amount (up to)					$ 120.3		$ 120.3
Term loan | Chestnut Borrower credit agreement | Conversion period one | London Interbank Offered Rate (LIBOR) | Chestnut Borrower, LLC, due 2024
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate					2.50%
Term loan | Chestnut Borrower credit agreement | Conversion period two | London Interbank Offered Rate (LIBOR) | Chestnut Borrower, LLC, due 2024
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate					2.75%
Senior Notes | 2024 Senior Notes
Debt Instrument [Line Items]
Debt instrument, repurchased face amount			$ 88.0
Debt instrument, redemption price, percentage			102.70%
Debt instrument, repurchase amount			$ 90.0
Loss on debt extinguishment			$ (3.0)
Senior Notes | 4.75% Senior Notes due in 2028
Debt Instrument [Line Items]
Debt instrument, repurchased face amount		$ 250.0
Debt instrument, interest rate, stated percentage		4.75%
Debt instrument, redemption price, percentage		102.00%
Repayment of outstanding principal amount	$ 45.0

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Earnings Per Share - Schedule of Reconciliation of Basic and Diluted Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$ 47	$ (24)	$ 18	$ (44)
Common Class A
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$ 14	$ (8)	$ 6	$ (14)
Weighted average number of common shares outstanding - basic and diluted (in share)	35	35	35	35
Loss per weighted average common share - basic and diluted (in dollars per share)	$ 0.41	$ (0.22)	$ 0.16	$ (0.41)
Common Class C
Basic and diluted income (loss) per share attributable to Clearway Energy, Inc. common stockholders
Net income (loss) attributable to Clearway Energy, Inc.	$ 33	$ (16)	$ 13	$ (30)
Weighted average number of common shares outstanding - basic and diluted (in share)	80	73	79	73
Loss per weighted average common share - basic and diluted (in dollars per share)	$ 0.41	$ (0.22)	$ 0.16	$ (0.41)

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Earnings Per Share - Antidilutive Equity Instruments Not Included in Calculation of Earnings Per Share (Details) - shares shares in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Common Class C | 2020 Convertible Notes
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Outstanding antidilutive equity instruments (in shares)	2	2

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Changes in Capital Structure - Equity Offering (Details)	6 Months Ended
	Jun. 30, 2020 USD ($) shares
Class of Stock [Line Items]
Aggregate sales price	$ 150,000,000
Shares of common stock sold (in shares) | shares	1,749,665
Proceeds from issuance or sale of equity	$ 38,000,000
Clearway Energy LLC
Class of Stock [Line Items]
Ownership interest (as a percentage)	57.41%
Clearway Energy LLC | CEG
Class of Stock [Line Items]
Ownership interest (as a percentage)	42.59%

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Changes in Capital Structure - Dividends (Details) - $ / shares					3 Months Ended			6 Months Ended
	Sep. 15, 2020	Sep. 01, 2020	Aug. 03, 2020	Jul. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Class of Stock [Line Items]
Preferred stock, authorized (in shares)					10,000,000			10,000,000		10,000,000
Par value - preferred stock (in usd per share)					$ 0.01			$ 0.01		$ 0.01
Subsequent Event
Class of Stock [Line Items]
Dividends payable, date declared				Jul. 30, 2020
Common stock, dividends, per share, declared (in dollars per share)			$ 0.3125	$ 0.3125
Dividends payable, date to be paid	Sep. 15, 2020
Dividends payable, date of record		Sep. 01, 2020
Common Class A
Class of Stock [Line Items]
Common stock, dividends, per share, cash paid (in dollars per share)					0.21	$ 0.21	$ 0.20	0.42	$ 0.40
Common Class C
Class of Stock [Line Items]
Common stock, dividends, per share, cash paid (in dollars per share)					$ 0.21	$ 0.21	$ 0.20	$ 0.42	$ 0.40

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Segment Reporting (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Segment Reporting Information [Line Items]
Operating revenues	$ 329		$ 284		$ 587	$ 501
Cost of operations	87		78		180	160
Depreciation, amortization and accretion	99		90		201	176
Impairment losses	0		19		0	19
General and administrative	12		7		21	13
Acquisition-related transaction and integration costs	0		1		1	2
Development costs	1		2		2	3
Operating Income	130		87		182	128
Equity in earnings of unconsolidated affiliates	16		11		3	14
Gain on sale of unconsolidated affiliate	49		0		49	0
Other income, net	0		1		2	4
Loss on debt extinguishment	0		(1)		(3)	(1)
Interest expense	(93)		(130)		(260)	(231)
Income (Loss) Before Income Taxes	102		(32)		(27)	(86)
Income tax expense (benefit)	26		4		4	(3)
Net income (loss)	76	$ (107)	(36)	$ (47)	(31)	(83)
Total Assets	9,736				9,736		$ 9,700
Accumulated Deficit
Segment Reporting Information [Line Items]
Net income (loss)	47	$ (29)	(24)	$ (20)
Thermal
Segment Reporting Information [Line Items]
Impairment losses			19			19
Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	329		284		587	501
Operating Segments | Conventional Generation
Segment Reporting Information [Line Items]
Operating revenues	107		84		210	163
Cost of operations	22		13		46	30
Depreciation, amortization and accretion	33		25		66	50
Impairment losses			0			0
General and administrative	0		0		0	0
Acquisition-related transaction and integration costs			0		0	0
Development costs	0		0		0	0
Operating Income	52		46		98	83
Equity in earnings of unconsolidated affiliates	1		2		3	4
Gain on sale of unconsolidated affiliate	0				0
Other income, net			0		0	1
Loss on debt extinguishment			0		0	0
Interest expense	(22)		(16)		(52)	(32)
Income (Loss) Before Income Taxes	31		32		49	56
Income tax expense (benefit)	0		0		0	0
Net income (loss)	31		32		49	56
Total Assets	2,674				2,674
Operating Segments | Renewables
Segment Reporting Information [Line Items]
Operating revenues	180		153		287	241
Cost of operations	39		35		75	67
Depreciation, amortization and accretion	59		58		121	113
Impairment losses			0			0
General and administrative	1		0		1	0
Acquisition-related transaction and integration costs			0		0	0
Development costs	0		0		0	0
Operating Income	81		60		90	61
Equity in earnings of unconsolidated affiliates	15		9		0	10
Gain on sale of unconsolidated affiliate	0				0
Other income, net			1		1	2
Loss on debt extinguishment			(1)		0	(1)
Interest expense	(42)		(89)		(151)	(148)
Income (Loss) Before Income Taxes	54		(20)		(60)	(76)
Income tax expense (benefit)	0		0		0	0
Net income (loss)	54		(20)		(60)	(76)
Total Assets	6,290				6,290
Operating Segments | Thermal
Segment Reporting Information [Line Items]
Operating revenues	42		47		90	97
Cost of operations	26		30		59	63
Depreciation, amortization and accretion	7		7		14	13
Impairment losses			19			19
General and administrative	2		0		3	1
Acquisition-related transaction and integration costs			0		0	0
Development costs	1		2		2	3
Operating Income	6		(11)		12	(2)
Equity in earnings of unconsolidated affiliates	0		0		0	0
Gain on sale of unconsolidated affiliate	0				0
Other income, net			0		1	0
Loss on debt extinguishment			0		0	0
Interest expense	(5)		(4)		(10)	(8)
Income (Loss) Before Income Taxes	1		(15)		3	(10)
Income tax expense (benefit)	0		0		0	0
Net income (loss)	1		(15)		3	(10)
Total Assets	613				613
Corporate
Segment Reporting Information [Line Items]
Operating revenues	0		0		0	0
Cost of operations	0		0		0	0
Depreciation, amortization and accretion	0		0		0	0
Impairment losses			0			0
General and administrative	9		7		17	12
Acquisition-related transaction and integration costs			1		1	2
Development costs	0		0		0	0
Operating Income	(9)		(8)		(18)	(14)
Equity in earnings of unconsolidated affiliates	0		0		0	0
Gain on sale of unconsolidated affiliate	49				49
Other income, net			0		0	1
Loss on debt extinguishment			0		(3)	0
Interest expense	(24)		(21)		(47)	(43)
Income (Loss) Before Income Taxes	16		(29)		(19)	(56)
Income tax expense (benefit)	26		4		4	(3)
Net income (loss)	(10)		$ (33)		(23)	$ (53)
Total Assets	$ 159				$ 159

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Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Income (loss) before income tax benefit	$ 102	$ (32)	$ (27)	$ (86)
Income tax expense (benefit)	$ 26	$ 4	$ 4	$ (3)
Effective income tax rate	25.50%	(12.50%)	(14.80%)	3.50%

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Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Related Party Transaction
General and administrative expense	$ 12.0	$ 7.0	$ 21.0	$ 13.0
RENOM
Related Party Transaction
Expenses from transactions with related party	9.0	7.0	18.0	14.0
Due to affiliate	9.0		9.0		$ 7.0
CEG
Related Party Transaction
Expenses from transactions with related party	2.0	$ 1.0	4.0	$ 3.0
General and administrative expense	$ 0.6		$ 1.2

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Leases - Lease Cost (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Leases [Abstract]
Operating lease cost - Fixed	$ 5	$ 2	$ 9	$ 4
Operating lease cost - Variable	3	3	5	7
Total lease cost	$ 8	$ 5	$ 14	$ 11

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Leases - Other Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Leases [Abstract]
ROU Assets - operating leases, net	$ 257		$ 223
Short-term lease liability - operating leases	7		7
Long-term lease liability - operating leases	260		227
Total lease liability	267		$ 234
Cash paid for operating leases	$ 10	$ 7
Weighted average remaining lease term (in years)	24 years		25 years
Weighted average discount rate (as a percentage)	4300000.00%		4400000.00%

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Leases - Maturities of Operating Lease Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Leases [Abstract]
Remainder of 2020	$ 8
2021	18
2022	18
2023	18
2024	18
Thereafter	359
Total lease payments	439
Less imputed interest	(172)
Total lease liability - operating leases	$ 267	$ 234

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Leases - Narrative (Details) $ in Millions	Jun. 30, 2020 USD ($) renewal_option	Dec. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Lease liability	$ 267	$ 234
Right of use assets, net	$ 257	$ 223
Oahu Solar Partnership
Lessee, Lease, Description [Line Items]
Lease period		35 years
Number of renewal options | renewal_option	2
Renewal period	5 years
Lease liability	$ 20	$ 21
Right of use assets, net	$ 18	$ 19

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Leases - Revenue Related to Leases (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Lessor, Lease, Description [Line Items]
Lease income	$ 244	$ 519	$ 423
Energy revenue
Lessor, Lease, Description [Line Items]
Lease income	159	300	259
Capacity revenue
Lessor, Lease, Description [Line Items]
Lease income	85	219	164
Conventional Generation
Lessor, Lease, Description [Line Items]
Lease income	86	222	166
Conventional Generation | Energy revenue
Lessor, Lease, Description [Line Items]
Lease income	1	3	2
Conventional Generation | Capacity revenue
Lessor, Lease, Description [Line Items]
Lease income	85	219	164
Renewables
Lessor, Lease, Description [Line Items]
Lease income	157	296	256
Renewables | Energy revenue
Lessor, Lease, Description [Line Items]
Lease income	157	296	256
Renewables | Capacity revenue
Lessor, Lease, Description [Line Items]
Lease income	0	0	0
Thermal
Lessor, Lease, Description [Line Items]
Lease income	1	1	1
Thermal | Energy revenue
Lessor, Lease, Description [Line Items]
Lease income	1	1	1
Thermal | Capacity revenue
Lessor, Lease, Description [Line Items]
Lease income	$ 0	$ 0	$ 0

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Leases - Minimum Future Rent Payments (Details) $ in Millions	Jun. 30, 2020 USD ($)
Leases [Abstract]
Remainder of 2020	$ 297
2021	444
2022	450
2023	259
2024	106
Thereafter	1,605
Total lease payments	$ 3,161

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Leases - Property, Plant and Equipment Related to Operating Leases (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Accumulated depreciation	$ (2,036)	$ (1,880)
Net property, plant and equipment	6,256	6,063
Assets Leased to Others
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	6,974	6,942
Accumulated depreciation	(1,769)	(1,649)
Net property, plant and equipment	$ 5,205	$ 5,293

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Asset Impairments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment losses	$ 0	$ 19	$ 0	$ 19
Thermal
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment losses		$ 19		$ 19