10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

☒	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Fiscal Year ended December 31, 2023.
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Transition period from                      to                       .

Commission file No. 001-15891

     NRG Energy, Inc.

(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation or organization)	41-1724239 (I.R.S. Employer Identification No.)
910 Louisiana Street, Houston, Texas (Address of principal executive offices)	77002 (Zip Code)

(713) 537-3000

(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 Exchange on Which Registered
Common Stock, par value $0.01	NRG	New York Stock Exchange

     Securities registered pursuant to Section 12(g) of the Act: None

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

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

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 has filed a report on and attestation to its management's assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C 7262(b)) by the registered public accounting firm that prepared or issued its audit report ☒

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. ☐

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b). ☐

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

As of the last business day of the most recently completed second fiscal quarter, the aggregate market value of the common stock of the registrant held by non-affiliates was approximately $6,266,747,422 based on the closing sale price of $37.39 as reported on the New York Stock Exchange.

Indicate the number of shares outstanding of each of the registrant's classes of common stock as of the latest practicable date.

Class	Outstanding at February 1, 2024
Common Stock, par value $0.01 per share	208,021,012

Documents Incorporated by Reference:

Portions of the Registrant's definitive Proxy Statement relating to its 2024 Annual Meeting of Stockholders

are incorporated by reference into Part III of this Annual Report on Form 10-K

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TABLE OF CONTENTS

	GLOSSARY OF TERMS	3
PART I		7
	Item 1 — Business	7
	Item 1A — Risk Factors	23
	Item 1B — Unresolved Staff Comments	38
	Item 1C — Cybersecurity	38
	Item 2 — Properties	40
	Item 3 — Legal Proceedings	41
	Item 4 — Mine Safety Disclosures	41
PART II		42
	Item 5 — Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	42
	Item 6 — Reserved	43
	Item 7 — Management's Discussion and Analysis of Financial Condition and Results of Operations	44
	Item 7A — Quantitative and Qualitative Disclosures About Market Risk	71
	Item 8 — Financial Statements and Supplementary Data	74
	Item 9 — Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	74
	Item 9A — Controls and Procedures	75
	Item 9B — Other Information	77
	Item 9C— Disclosure Regarding Foreign Jurisdictions that Prevent Inspections	77
PART III		78
	Item 10 — Directors, Executive Officers and Corporate Governance	78
	Item 11 — Executive Compensation	78
	Item 12 — Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	78
	Item 13 — Certain Relationships and Related Transactions, and Director Independence	79
	Item 14 — Principal Accounting Fees and Services	79
PART IV		80
	Item 15 — Exhibits, Financial Statement Schedules	80
EXHIBIT INDEX		163
	Item 16 — Form 10-K Summary	167

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Glossary of Terms

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

ACE	Affordable Clean Energy
Acquisition	The acquisition of Vivint Smart Home, Inc. by NRG completed on March 10, 2023
Adjusted EBITDA	Adjusted earnings before interest, taxes, depreciation and amortization
AESO	Alberta Electric System Operator
ARO	Asset Retirement Obligation
ASC	The FASB Accounting Standards Codification, which the FASB established as the source of authoritative GAAP
ASR	Accelerated Share Repurchases
ASU	Accounting Standards Updates – updates to the ASC
AUC	Alberta Utilities Commission
BTU	British Thermal Unit
Business	NRG Business, which serves business customers
CAA	Clean Air Act
CAISO	California Independent System Operator
CAMT	15% Corporate Alternative Minimum Tax enacted by the IRA on August 16, 2022
CDD	Cooling Degree Day
CFTC	U.S. Commodity Futures Trading Commission
CO2	Carbon Dioxide
CO2e	Carbon Dioxide Equivalents
Company	NRG Energy, Inc.
Convertible Senior Notes	As of December 31, 2023, consists of NRG’s $575 million unsecured 2.75% Convertible Senior Notes due 2048
Cottonwood	Cottonwood Generating Station, a 1,166 MW natural gas-fueled plant
CPP	Clean Power Plan
CPUC	California Public Utilities Commission
CWA	Clean Water Act
D.C. Circuit	U.S. Court of Appeals for the District of Columbia Circuit
DSI	Dry Sorbent Injection
DSU	Deferred Stock Unit
Dth	Dekatherms
Dual fuel customers	Customer that have both electricity and natural gas service with the Company
Economic gross margin	Sum of retail revenue, energy revenue, capacity revenue and other revenue, less cost of fuels, purchased energy and other cost of sales
EGU	Electric Generating Unit
EPA	U.S. Environmental Protection Agency
EPC	Engineering, Procurement and Construction
ERCOT	Electric Reliability Council of Texas, the Independent System Operator and the regional reliability coordinator of the various electricity systems within Texas
ESP	Electrostatic Precipitator
ESPP	NRG Energy, Inc. Amended and Restated Employee Stock Purchase Plan
Exchange Act	The Securities Exchange Act of 1934, as amended
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FGD	Flue gas desulfurization
FPA	Federal Power Act

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FTRs	Financial Transmission Rights
GAAP	Generally accepted accounting principles in the United States
GHG	Greenhouse Gas
Green Mountain Energy	Green Mountain Energy Company
GW	Gigawatts
GWh	Gigawatt Hours
HDD	Heating Degree Day
Heat Rate	A measure of thermal efficiency computed by dividing the total BTU content of the fuel burned by the resulting kWhs generated. Heat rates can be expressed as either gross or net heat rates, depending whether the electricity output measured is gross or net generation and is generally expressed as BTU per net kWh
Home	NRG Home, which serves residential customers
ICE	Intercontinental Exchange
IoT	Internet of Things
IRA	Inflation Reduction Act
ISO	Independent System Operator, also referred to as RTOs
ISO-NE	ISO New England Inc.
Ivanpah	Ivanpah Solar Electric Generation Station, a 391 MW solar thermal power plant located in California's Mojave Desert in which NRG owns 54.5% interest
kWh	Kilowatt-hours
LaGen	Louisiana Generating LLC
LIBOR	London Inter-Bank Offered Rate
LSEs	Load Serving Entities
LTIPs	Collectively, the NRG LTIP and the Vivint LTIP
MDth	Thousand Dekatherms
Midwest Generation	Midwest Generation, LLC
MISO	Midcontinent Independent System Operator, Inc.
MMBtu	Million British Thermal Units
MMDth	Million Dekatherms
MW	Megawatts
MWh	Saleable megawatt hour net of internal/parasitic load megawatt-hour
NAAQS	National Ambient Air Quality Standards
NEPOOL	New England Power Pool
NERC	North American Electric Reliability Corporation
NERC-CIP	North American Electric Reliability Corporation Critical Infrastructure Protection
Net Capacity Factor	The net amount of electricity that a generating unit produces over a period of time divided by the net amount of electricity it could have produced if it had run at full power over that time period. The net amount of electricity produced is the total amount of electricity generated minus the amount of electricity used during generation
Net Exposure	Counterparty credit exposure to NRG, net of collateral
Net Generation	The net amount of electricity produced, expressed in kWhs or MWhs, that is the total amount of electricity generated (gross) minus the amount of electricity used during generation
NIST	National Institute of Standards and Technology
Nodal	Nodal Exchange is a derivatives exchange
NOL	Net Operating Loss
NOx	Nitrogen Oxides
NPNS	Normal Purchase Normal Sale
NRC	U.S. Nuclear Regulatory Commission
NRG	NRG Energy, Inc.

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NRG LTIP	NRG Energy, Inc. Amended and Restated Long-Term Incentive Plan
Nuclear Decommissioning Trust Fund	NRG's nuclear decommissioning trust fund assets, which were for the Company's portion of the decommissioning of the STP, units 1 & 2 through the sale of STP on November 1, 2023
NYISO	New York Independent System Operator
NYMEX	New York Mercantile Exchange
OCI/OCL	Other Comprehensive Income/(Loss)
ORDC	Operating Reserve Demand Curve
ORDPA	Online Reliability Deployment Price Adder
PCI DSS	Payment Card Industry Data Security Standard
Peaking	Units expected to satisfy demand requirements during the periods of greatest or peak load on the system
Petra Nova	Petra Nova Parish Holdings, LLC
PJM	PJM Interconnection, LLC
PM2.5	Particulate Matter that has a diameter of less than 2.5 micrometers
PPA	Power Purchase Agreement
PUCT	Public Utility Commission of Texas
RCRA	Resource Conservation and Recovery Act of 1976
Receivables Facility	NRG Receivables LLC, a bankruptcy remote, special purpose, wholly-owned indirect subsidiary of the Company's $1.4 billion accounts receivables securitization facility due 2024, which was last amended on October 6, 2023
Receivables Securitization Facilities	Collectively, the Receivables Facility and the Repurchase Facility
RECs	Renewable Energy Certificates
Renewable PPA	A third-party PPA entered into directly with a renewable generation facility for the offtake of the RECs or other similar environmental attributes generated by such facility, coupled with the associated power generated by that facility
Renewables	Consists of the following projects in which NRG has an ownership interest: Ivanpah and solar generating stations located at various NFL Stadiums
Renewables Platform	The renewable operating and development platform sold to Global Infrastructure Partners with NRG's interest in NRG Yield
REP	Retail electric provider
Repurchase Facility	NRG's $150 million uncommitted repurchase facility related to the Receivables Facility due 2024, which was last amended on October 6, 2023
Revolving Credit Facility	The Company's $4.3 billion revolving credit facility due 2028, which was last modified on March 13, 2023
RGGI	Regional Greenhouse Gas Initiative
RMR	Reliability Must-Run
RPS	Renewable Portfolio Standards
RPSU	Relative Performance Stock Unit
RSU	Restricted Stock Unit
RTO	Regional Transmission Organization
SCR	Selective Catalytic Reduction Control System
SEC	U.S. Securities and Exchange Commission
Securities Act	The Securities Act of 1933, as amended
Senior Notes	As of December 31, 2023, NRG's $4.0 billion outstanding unsecured senior notes consisting of $375 million of the 6.625% senior notes due 2027, $821 million of 5.75% senior notes due 2028, $733 million of the 5.25% senior notes due 2029, $500 million of the 3.375% senior notes due 2029, $1.0 billion of the 3.625% senior notes due 2031 and $480 million of the 3.875% senior notes due 2032

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Senior Secured First Lien Notes	As of December 31, 2023, NRG’s $3.2 billion outstanding Senior Secured First Lien Notes consists of $600 million of the 3.75% Senior Secured First Lien Notes due 2024, $500 million of the 2.0% Senior Secured First Lien Notes due 2025, $900 million of the 2.45% Senior Secured First Lien Notes due 2027, $500 million of the 4.45% Senior Secured First Lien Notes due 2029 and $740 million of the 7.000% Senior Secured First Lien Notes due 2033
Series A Preferred Stock	As of December 31, 2023, NRG's Series A Preferred Stock consists of 650,000 outstanding shares of the 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, with a $1,000 liquidation preference per share
Services	NRG Services, which primarily includes the services businesses acquired in the Direct Energy acquisition and the Goal Zero business
SO2	Sulfur Dioxide
SOFR	Secured overnight financing rate
South Central Portfolio	NRG's South Central Portfolio, which owned and operated a portfolio of generation assets consisting of Bayou Cove, Big Cajun-I, Big Cajun-II, Cottonwood and Sterlington, was sold on February 4, 2019. NRG is leasing back the Cottonwood facility through May 2025
S&P	Standard & Poor's
STP	South Texas Project — nuclear generating facility located near Bay City, Texas in which NRG owned a 44% interest. NRG closed on the sale of its interest in STP on November 1, 2023
STPNOC	South Texas Project Nuclear Operating Company
Tax Act	The Tax Cuts and Jobs Act of 2017
TDSP	Transmission/distribution service provider
Texas Genco	Texas Genco LLC
TSR	Total Shareholder Return
TWh	Terawatt Hours
U.S.	United States of America
VaR	Value at Risk
VIE	Variable Interest Entity
Vivint LTIP	Vivint Smart Home, Inc. Long-Term Incentive Plan assumed by NRG pursuant to merger between NRG and Vivint
Winter Storm Elliott	A major winter storm that had impacts across the majority of the United States and parts of Canada occurring in December 2022
Winter Storm Uri	A major winter and ice storm that had widespread impacts across North America occurring in February 2021

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PART I

Item 1 — Business

General

NRG Energy, Inc., or NRG or the Company, sits at the intersection of energy and home services. NRG is a leading energy and home services company fueled by market-leading brands, proprietary technologies and complementary sales channels. Across the U.S. and Canada, NRG delivers innovative, sustainable solutions, predominately under brand names such as NRG, Reliant, Direct Energy, Green Mountain Energy and Vivint, while also advocating for competitive energy markets and customer choice. The Company has a customer base that includes approximately 8 million residential consumers in addition to commercial, industrial, and wholesale customers, supported by approximately 13 GW of generation as of December 31, 2023.

NRG sold 152 TWhs of electricity and 1,892 MMDth of natural gas in 2023, making it one of the largest competitive energy retailers in the U.S. As of the end of 2023, NRG had recurring electricity and/or natural gas sales in 25 U.S. states, the District of Columbia, and 8 provinces in Canada, as well as Vivint served customers in all 50 U.S. states. NRG's retail brands, collectively, have the largest share of competitively served residential electric customers in Texas and nationwide.

The following chart represents NRG's sales volumes for the year ended December 31, 2023:

Strategy

NRG's strategy is to maximize stakeholder value by being a leader in the emerging convergence of energy and smart automation in the home and business. Through a diversified supply strategy, the Company sells reliable electricity and natural gas to its customers in the markets it serves, while also providing innovative home solutions to customers. NRG's unique combination of assets and capabilities enables the Company to develop and sell highly differentiated offerings that bring together every day essential services like powering and securing the home through a seamless and integrated experience. This strategy is intended to enable the Company to optimize its unique integrated platform to delight customers, generate recurring cash flow, significantly strengthen earnings and cost competitiveness, and lower risk and volatility. Sustainability is a philosophy that underpins and facilitates value creation across NRG's business for its stakeholders. It is an integral piece of NRG's strategy and ties directly to business success, reduced risks and enhanced reputation.

To effectuate the Company’s strategy, NRG is focused on: (i) serving the energy needs of end-use residential, commercial and industrial, and wholesale counterparties in competitive markets and optimizing on additional revenue opportunities through its multiple brands and channels; (ii) offering a variety of energy products and services, including renewable energy solutions and smart home products and services that are differentiated by innovative features, premium service, integrated platforms, sustainability and loyalty/affinity programs; (iii) excellence in operating performance of its assets; (iv) achieving the optimal mix of supply to serve its customer load requirements through a diversified supply strategy; and (v) engaging in disciplined and transparent capital allocation.

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The following transactions were completed during 2023 in furtherance of the Company’s strategy: (i) the March 10, 2023 acquisition of Vivint Smart Home, a leading smart home platform company; (ii) portfolio optimization, including the sale of the Company’s 44% equity interest in STP for $1.7 billion; and (iii) disciplined capital allocation through the execution of $1.2 billion in share repurchases and $1.4 billion in debt reduction.

Business Overview

The Company’s core businesses are the sale of electricity and natural gas to residential, commercial and industrial and wholesale customers, supported by the Company's wholesale electric generation, as well as the sale of smart home products and services. NRG manages its electricity and natural gas operations based on the combined results of the retail and wholesale generation businesses with a geographical focus. Vivint Smart Home operations are reported within the Vivint Smart Home segment.

The Company's business is segmented as follows:

•Texas, which includes all activity related to customer, plant and market operations in Texas, other than Cottonwood;

•East, which includes all activity related to customer, plant and market operations in the East;

•West/Services/Other, which primarily includes the following assets and activities: (i) all activity related to customer, plant and market operations in the West and Canada, (ii) the Services businesses, (iii) activity related to the Cottonwood facility and other investments;

•Vivint Smart Home; and

•Corporate activities.

In Texas, the Company’s generation supply is fully integrated with its retail load. This integrated model provides the advantage of being able to supply a portion of the Company’s retail customers with electricity from the Company’s assets, which reduces the need to sell electricity to, and buy electricity from, other institutions and intermediaries, resulting in more stable earnings and cash flows, lower transaction costs and less credit exposure. The integrated model also results in a reduction in actual and contingent collateral through offsetting transactions, thereby reducing transactions with third parties.

The integrated model consists of three core functions in each geographic segment above: Customer Operations, Market Operations and Plant Operations.

Customer Operations

Customer Operations is responsible for growing and retaining the customer base and delivering an outstanding customer experience. This includes acquisition and retention of all of NRG’s residential, small commercial, commercial and industrial, and government customers. NRG employs a multi-brand strategy that leverages a wide array of sales and partnership channels, direct face-to-face sales channels, call centers, websites, and brokers. Go-to-market activities include market strategy planning and development, product innovation, offer design, campaign execution, marketing and creative services, and selling. Customer portfolio maintenance and retention activities include fulfillment, billing, payment processing, collections, customer service, issue resolution, and contract renewals. NRG provides energy and related services at either fixed, indexed or month-to-month prices. Home customers typically contract for terms ranging from one month to five years, while Business contracts are often between one year and five years in length. Throughout all Customer Operations activities, the customer experience is kept at the forefront to inform decision-making and optimize retention, while creating supporters and advocates for NRG’s brands in the market. Customer Operations comprises three end-use customer facing teams: NRG Home, which serves residential customers, NRG Business, which serves business customers, and NRG Services, which primarily includes the Services businesses.

Product Offerings

NRG sells a variety of products to residential and small commercial customers, including retail electricity and energy management, natural gas, line and surge protection products, HVAC installation, repair and maintenance, home protection products, carbon offsets, back-up power stations, portable power, portable solar and portable lighting. Home and Services customers make purchase decisions based on a variety of factors, including price, incentive, customer service, brand, innovative offers/features and referrals from friends and family. Through its broad range of service offerings and value propositions, NRG seeks to attract, retain, and increase the value of its customer relationships. NRG's brands are recognized for exemplary customer service, innovative smart energy and technology product offerings, and environmentally-friendly solutions.

The Company provides power and natural gas to the business-to-business markets in North America, as well as retail services, including demand response, commodity sales, energy efficiency and energy management solutions to Business customers. The Company is an integrated provider of supply and distributed energy resources and focuses on distributed products and services as businesses seek greater reliability, cleaner power and other benefits that they cannot obtain from the grid. These solutions include system power, distributed generation, renewable and low-carbon products, carbon management

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and specialty services, backup generation, storage and distributed solar, demand response, and energy efficiency and advisory services.

Market Operations

Market Operations has two primary objectives: to supply energy to customers in the most cost-efficient manner and to maximize the value of the Company's assets in satisfying its customer load requirements. These objectives are intended to reduce supply costs and maximize earnings with predictable cash flows.

Power and natural gas are the two main commercial groups within Market Operations.

Power

The power commercial group is responsible for end-use electricity supply including power plant optimization and certain fuel supply. To meet the market operations objectives, NRG enters into supply, power and gas hedging agreements via a wide range of products and contracts, including (i) physical and financial commodity instruments, (ii) fuel supply and transportation contracts, (iii) PPAs and Renewable PPAs and (iv) capacity and other contracted revenue or supply sources, as further discussed below.

In addition, because changes in power prices in the markets where NRG operates are generally correlated to changes in natural gas prices, NRG uses hedging strategies that may include power and natural gas forward purchases and sales contracts to manage commodity price risk.

Physical and Financial Commodity Instruments

NRG trades power, natural gas, environmental, weather and other physical and financial commodity related products, including forwards, futures, options and swaps. NRG enters into these instruments primarily to manage price and delivery risk, optimize physical and contractual assets in the portfolio, manage working capital requirements, reduce the carbon exposure in its business and to comply with laws and regulations.

Fuel Supply and Transportation Contracts

NRG's fuel requirements consist of various forms of fossil fuel. The prices of fossil fuels can be volatile. The Company obtains its fossil fuels from multiple suppliers and through multiple transporters. Although availability is generally not an issue, localized shortages, transportation availability, delays arising from extreme weather conditions and supplier financial stability issues can and do occur. The preceding factors related to the sources and availability of raw materials are fairly uniform across the Company's business and fuel products used. NRG's primary fuel requirements consist of the following:

Natural Gas — NRG operates a fleet of mid-merit and peaking natural gas plants. Fuel needs are managed by the natural gas commercial group, generally on a spot basis, as the Company does not believe it is prudent to forward purchase natural gas for these types of units as the dispatch is highly unpredictable. Natural gas storage and transportation contracts are utilized to reduce daily volatility.

Coal —NRG actively manages its coal requirements based on forecasted generation, market volatility and its inventory on site. The Company believes it is adequately hedged, using forward coal supply agreements, for its domestic coal consumption for 2024. As of December 31, 2023, NRG had purchased forward contracts to provide fuel for the Company's expected requirements for 2024. For the domestic fleet, NRG purchased approximately 13 million tons of coal in 2023, almost all of which was Powder River Basin coal. For fuel transport, NRG has entered into various rail transportation and rail car lease agreements with varying tenures, which will provide for the Company's transportation requirements of Powder River Basin coal for the next two years.

Renewable PPAs

The Company's strategy is to procure mid to long-term renewable generation through power purchase agreements. As of December 31, 2023, NRG has entered into Renewable PPAs totaling approximately 1.9 GW with third-party project developers and other counterparties, of which approximately 1.1 GW are operational. The average tenure of these agreements is eleven years. The Company expects to continue evaluating and executing similar agreements that support the needs of the business. The total GW entered into through Renewable PPAs may be impacted by contract terminations when they occur.

Capacity and Other Contracted Revenue or Supply Sources

NRG's revenues and/or cash flows, primarily in the East and West, benefit from capacity/demand payments and other contracted revenue sources, originating from market clearing capacity prices, tolling arrangements and other long-term contractual arrangements.

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Natural Gas

The natural gas commercial group is responsible for costing, logistics and supply for all of NRG's residential, commercial and industrial, and wholesale customers. NRG has contractual rights to natural gas transportation and storage assets across its footprint that allow for optimal supply economics in support of its various businesses. NRG's diversified load coupled with this asset portfolio enables the Company to deliver supply economically while providing incremental optimization activities when market conditions allow. The scale of the natural gas operation extends from the wellhead (through its producer services business) to end use customers (through NRG's various sales channels). This scale, coupled with the Company's associated assets, gas system platform and people, create significant value across North America.

Plant Operations

The Company owns and leases a diversified wholesale generation portfolio with approximately 13 GW of fossil fuel, and renewable generation capacity at 19 plants as of December 31, 2023. The Company's wholesale generation assets are diversified by fuel-type and dispatch level, which helps mitigate the risks associated with fuel price volatility and market demand cycles. NRG continually evaluates its generation portfolio to focus on asset optimization opportunities and the locational value of its generation assets in each of the markets where the Company participates, as well as opportunities for the development of new generation.

The following table summarizes NRG's generation portfolio as of December 31, 2023:

	(In MW)(a)
Type	Texas	East	West/Services/Other(b)	Total
Natural gas	4,353	80	1,279	5,712
Coal	4,174	1,948	605	6,727
Oil	—	455	—	455
Utility Scale Solar	—	—	216	216
Battery Storage	2	—	—	2
Total generation capacity	8,529	2,483	2,100	13,112

(a)Utility Scale Solar is described in MW on an alternating current basis. MW figures provided represent nominal summer net MW capacity of power generated as adjusted for the Company's owned interest

(b)Includes proportionate share of equity owned investments

Plant Operations is responsible for operating the Company's generation facilities at the highest standards of safety and regulatory compliance, and includes (i) operations and maintenance, (ii) asset management, and (iii) development, engineering and construction.

Operations & Maintenance

NRG operates and maintains its generation portfolio, as well as approximately 6,500 MW of additional coal, natural gas and wind generation capacity at 15 plants operated on behalf of third parties, as of December 31, 2023, using prudent industry practices for the safe, reliable and economic generation of electricity in compliance with all local, state and federal requirements. The Company follows a consistent set of operating requirements, including a solid base of training, required adherence to specific safety and environmental limits, procedure and checklist usage, and the implementation of continuous process improvement through incident investigations.

NRG uses best-in-class maintenance practices for preventive, predictive, and corrective maintenance planning. The Company’s strategic planning process evaluates equipment condition, performance, and obsolescence to support the development of a comprehensive work scope and schedule for long-term performance.

Asset Management

NRG manages all aspects of its generation portfolio to optimize the lifecycle value of the assets, consistent with the Company’s goals. The Company evaluates capital projects required for continued operation and strategic enhancement of the assets, provides quality assurance on capital outlays, and assesses the impact of rules, regulations, and laws on business profitability. In addition, the Company manages its long-term contracts, PPAs, and real estate holdings and provides third-party asset management services.

Development, Engineering & Construction

NRG develops, engineers and executes major plant modifications, “new build” generation and energy storage projects that enhance the value of its generation portfolio and provide options to meet generation growth needs in the retail markets it serves, in accordance with the Company’s strategic goals. These projects have included gas-fired generation development and

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construction, coal to gas conversions, grid scale energy storage development, grid scale renewable construction, and asset demolition, remediation and reclamation work.

Vivint Smart Home

In March 2023, NRG completed the acquisition of Vivint Smart Home, which is a leading smart home platform that provides subscribers with technology, products and services to create a smarter, greener, safer home. A smart home has multiple devices integrated into a single expandable platform that incorporates artificial intelligence and machine-learning in its operating system allowing customers to interact with and manage their home from anywhere via the Vivint app on their smart device. Vivint Smart Home enables a customized solution for the home using integrated smart cameras (indoor, outdoor and doorbell), locks, lights, thermostats, garage door control and a host of other safety and security sensors.

Vivint Smart Home provides a fully integrated solution for consumers, including hardware, software, sales, installation by trained and experienced in-home service professionals, customer service, technical support and professional monitoring. This seamless integration of high-quality products and services resulted in an average subscriber lifetime of approximately nine years as of December 31, 2023. The Company believes its ability to offer related or adjacent products and services that leverage the existing smart home platform, as well as energy services, can extend the average subscriber lifetime and increase the lifetime value of subscribers. Vivint Smart Home's cloud-based home platform currently manages more than 30 million in-home devices as of December 31, 2023. The average subscriber on Vivint Smart Home's cloud-based home platform engages with the smart home app approximately 16 times per day and has approximately 15 devices in its home.

Through the addition of Vivint Smart Home, NRG identified opportunities to improve gross margin, customer retention and customer lifetime value.

Operational Statistics

The following statistics represent the Company's retail load and customer count:

	Year ended December 31,
	2023	2022	2021
Sales volumes - Electricity (in GWh)
Home - Texas	40,032	43,155	42,397
Home - East	12,838	13,269	14,108
Home - West/Services/Other	2,243	2,250	2,252
Business - Texas	40,250	38,447	34,367
Business - East	46,438	47,724	53,204
Business - West/Services/Other	10,393	10,231	10,625
Total Load	152,194	155,076	156,953
Sales volumes - Natural gas (in MDth)
Home - East	49,990	53,051	50,417
Home - West/Services/Other	75,150	92,035	97,272
Business - East	1,587,052	1,618,946	1,620,036
Business - West/Services/Other	179,888	154,074	109,021
Total Load	1,892,080	1,918,106	1,876,746

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	Year ended December 31,
	2023	2022	2021
Customer count - Electricity customers(a)(b) (in thousands)
Home - Texas
Average retail	2,878	2,961	3,040
Ending retail	2,928	2,859	3,010
Home - East
Average retail	1,466	1,408	1,484
Ending retail	1,752	1,381	1,402
Home - West/Services/Other
Average retail(c)	393	383	525
Ending retail(c)	404	390	512
Customer count - Natural gas customers(b) (in thousands)
Home - East
Average retail	390	375	360
Ending retail	385	380	364
Home - West/Services/Other
Average retail	381	416	452
Ending retail	358	396	434
Total Customer count (in thousands)
Average retail - Home - Electricity and Natural gas	5,508	5,543	5,861
Average - Vivint Smart Home(d)	2,008	—	—
Ending retail - Home - Electricity and Natural gas	5,827	5,406	5,722
Ending - Vivint Smart Home(d)	2,043	—	—
Total Ending retail and Vivint Smart Home	7,870	5,406	5,722
(a) Includes Services customers
(b) Dual fuel customers are included within electricity customer counts only
(c) Includes 135 thousand whole home warranty customers as of December 31, 2021. The whole home warranty business was sold in January 2022
(d) Vivint Smart Home subscribers includes customers that also purchase other NRG products

The following are industry statistics for the Company's fossil and nuclear plants, as defined by the NERC:

Annual Equivalent Availability Factor, or EAF — Measures the percentage of maximum generation available over time as the fraction of net maximum generation that could be provided over a defined period of time after all types of outages and deratings, including seasonal deratings, are taken into account.

Net Heat Rate — The net heat rate represents the total amount of fuel in BTU required to generate one net kWh provided.

Net Capacity Factor — The net amount of electricity that a generating unit produces over a period of time divided by the net amount of electricity it could have produced if it had run at full power over that time period. The net amount of electricity produced is the total amount of electricity generated minus the amount of electricity used during generation by the station.

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The tables below present these performance metrics for the Company's generation portfolio, including leased facilities, for the years ended December 31, 2023 and 2022:

	Year Ended December 31, 2023
			Fossil and Nuclear Plants (a)
	Net Owned Capacity (MW)	Net Generation (In thousands of MWh) (a)	Annual Equivalent Availability Factor		Average Net Heat Rate BTU/kWh	Net Capacity Factor
Texas	8,529	30,776	74.2	%	11,175	35.4	%
East	2,483	2,016	85.5	%	13,007	6.6	%
West/Services/Other	1,169	5,903	73.5	%	7,449	56.8	%

(a)Excludes equity method investments

	Year Ended December 31, 2022
			Fossil and Nuclear Plants (a)
	Net Owned Capacity (MW)	Net Generation (In thousands of MWh) (a)	Annual Equivalent Availability Factor		Average Net Heat Rate BTU/kWh	Net Capacity Factor
Texas	10,027	37,275	69.5	%	10,733	41.8	%
East	4,285	7,282	78.1	%	11,959	17.3	%
West/Services/Other	1,172	6,676	84.5	%	7,442	64.9	%

(a)Excludes equity method investments

The generation performance by region for the three years ended December 31, 2023, 2022 and 2021 is shown below:

	Net Generation
(In thousands of MWh)	2023	2022	2021
Texas
Coal	15,576	18,860	18,876
Gas	7,333	8,763	8,846
Nuclear (a)	7,867	9,652	9,198
Total Texas	30,776	37,275	36,920
East
Coal	1,328	6,738	5,774
Oil	3	7	201
Gas	685	537	1,519
Total East (b)	2,016	7,282	7,494
West/Services/Other
Gas	5,899	6,669	7,941
Renewables	4	7	8
Total West/Services/Other (c)	5,903	6,676	7,949
Total generation performance	38,695	51,233	52,363

(a)Reflects the Company's undivided interest in total MWh generated by STP. The Company sold its interest in STP on November 1, 2023

(b)Includes gas generation of 855 thousand MWh and oil generation of 199 thousand MWh for the year ended December 31, 2021, that was sold to Generation Bridge on December 1, 2021

(c)Includes gas generation of 2,445 thousand MWh for the year ended December 31, 2021, that was sold to Generation Bridge on December 1, 2021

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Competition

While there has been consolidation in the competitive retail energy space over the past few years, there is still considerable competition for customers. In Texas, there is healthy competition in deregulated areas and customers can choose providers based on the most appealing offers. Outside of Texas, electricity retailers compete with the incumbent utilities, in addition to other retail electric providers, which can inhibit competition depending on the market rules of the state. There is a high degree of fragmentation, with both large and small competitors offering a range of value propositions, including value, rewards, and sustainability-based offerings.

Wholesale generation is highly fragmented and diverse in terms of industry structure by region. As such, there is wide variation in terms of the capabilities, resources, nature and identities of the Company’s competitors depending on the market. Competitors include regulated utilities, municipalities, cooperatives, other independent power producers, and power marketers or trading companies, including those owned by financial institutions.

The smart home market is an expanding global opportunity and is in the early stages of broad consumer adoption. It is highly competitive and fragmented. Major competitors range from large-cap technology companies seeking to expand their core market opportunity who predominantly offer do-it-yourself ("DIY") devices that put a large burden on homeowners to self-install and support many devices, to security-based providers, as well as industrial and telecommunications companies that offer connected home experiences. Vivint Smart Home provides the full smart home experience, with an end-to-end solution that includes a wide range of unique capabilities and use cases. Currently, the vast majority of competitors do not offer comprehensive smart home solutions and accompanying services.

Seasonality and Price Volatility

The sale of power and natural gas to retail customers are seasonal businesses with the demand for power generally peaking during the summer, and the demand for natural gas generally peaking during the winter. As a result, net working capital requirements for the Company's retail operations generally increase during summer and winter months along with the higher revenues, and then decline during off-peak months. Weather may impact operating results and extreme weather conditions could have a material impact. The rates charged to retail customers may be impacted by fluctuations in total power prices and market dynamics, such as the price of natural gas, transmission constraints, competitor actions, and changes in market heat rates.

Annual and quarterly operating results of the Company's generation portfolio can be significantly affected by weather and energy commodity price volatility. Significant other events, such as the demand for natural gas, interruptions in fuel supply infrastructure and relative levels of hydroelectric capacity can increase seasonal fuel and power price volatility. The preceding factors related to seasonality and price volatility are fairly uniform across the regions in which the Company operates.

Market Framework

NRG sells electricity, natural gas and related products and services, and smart home products and services to customers throughout the U.S. and Canada. In most of the states and regions that have introduced retail consumer choice, NRG competitively offers electricity, natural gas, portable power and other value-enhancing services to customers. Each retail consumer choice state or province establishes its own retail competition laws and regulations, and the specific operational, licensing, and compliance requirements vary by state or province. Regulated terms and conditions of default service, as well as any movement to replace default service with competitive services, as is done in ERCOT, can affect customer participation in retail competition. In Canada, NRG sells energy and related services to residential and commercial customers in the province of Alberta pursuant both to a regulated rate service governed by provincial regulations as well as a competitive service with rates set by market forces. Sales of energy to commercial customers take place in other provinces as well. The attractiveness of NRG's retail offerings may be impacted by the rules, regulations, market structure and communication requirements from public utility commissions in each state and province.

NRG's fleet of power plants which it owns, operates or manages are located in organized energy markets, known as RTOs or ISOs. Each organized market administers day-ahead and real-time centralized bid-based energy and ancillary services markets pursuant to tariffs approved by FERC, or in the case of ERCOT, market rules approved by the PUCT. These tariffs and rules dictate how the energy markets operate, how market participants make bilateral sales with one another and how entities with market-based rates are compensated. Established prices reflect the value of energy at the specific location and time it is delivered, which is known as the Locational Marginal Price. Each market is subject to market mitigation measures designed to limit the exercise of locational market power. These market structures facilitate NRG's sale of power and capacity products at market-based rates.

Other than ERCOT and AESO, each of the ISO regions also operates a capacity or resource adequacy market that provides an opportunity for generating and demand response resources to earn revenues to offset their fixed costs that are not recovered in the energy and ancillary services markets. The ISOs are also responsible for transmission planning and operations.

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Texas

NRG's business in Texas is subject to standards and regulations adopted by the PUCT and ERCOT1, including the requirement for retailers to be certified by the PUCT in order to contract with end-users to sell electricity. The ERCOT market is one of the nation's largest and, historically, fastest growing power markets. ERCOT is an energy-only market. The majority of the retail load in the ERCOT market region is served by competitive retail suppliers, except certain areas that have not opted into competitive consumer choice and are served by municipal utilities and electric cooperatives.

East

While most of the states in the East region of the U.S. have introduced some level of retail consumer choice for electricity and/or natural gas, the incumbent utilities currently provide default service in most of the states and as a result typically serve the majority of residential customers. NRG’s retail activities in the East are subject to standards and regulations adopted by the ISOs, state public utility commissions and legislators, including the requirement for retailers to be certified in each state in order to contract with end-users to sell electricity.

Power plants owned, operated or managed by NRG and NRG's demand response assets located in the East region of the U.S. are within the control areas of PJM, NYISO and MISO. Each of the market regions in the East region provides for robust competition in the day-ahead and real-time energy and ancillary services markets. Additionally, the assets in the East region receive a significant portion of their revenues from capacity markets. PJM uses a forward capacity auction, while NYISO uses a month-ahead capacity auction. MISO has an annual auction. Capacity market prices are sensitive to design parameters, as well as additions of new capacity. PJM operates a pay-for-performance model where capacity payments are modified based on real-time generator performance. In such markets, NRG’s actual capacity revenues will be the combination of cleared auction prices times the quantity of MW cleared, plus the net of any over-performance "bonus payments" and any under-performance charges. Additionally, bidding rules allow for the incorporation of a risk premium into generator bids.

West

In the West region of the U.S., NRG owns equity interests, operates or manages power plants located entirely within the CAISO footprint. The CAISO operates day-ahead and real-time locational markets for energy and ancillary services, while managing congestion primarily through nodal prices. The CAISO system facilitates NRG's sale of power, ancillary services and capacity products at market-based rates, either within the CAISO's centralized energy and ancillary service markets or bilaterally. The CPUC also determines capacity requirements for LSEs and for specified local areas utilizing inputs from the CAISO. Both the CAISO and CPUC rules require LSEs to contract with sufficient generation resources in order to maintain minimum levels of generation within defined local areas. Additionally, the CAISO has independent authority to contract with needed resources under certain circumstances, typically either when LSEs have failed to procure sufficient resources, or system conditions change unexpectedly.

Canada

In Canada, NRG sells to residential and commercial retail customers in Alberta, within the AESO footprint, under both regulated rates approved by the AUC as well as through competitive service. The Company's regulated rates are approved through periodic rate applications that establish rates for power and gas sales as well as for recovery of other costs associated with operating the regulated business. In addition, the Company sells energy to commercial customers in other provinces. All sales and operations are subject to applicable federal and provincial laws and regulations.

Vivint Smart Home

Vivint Smart Home operates in states that regulate in some manner the sale, installation, servicing, monitoring or maintenance of smart home and electronic security systems. Vivint Smart Home and Vivint Smart Home sales representatives are typically required to obtain and maintain licenses, certifications or similar permits from governmental entities as a condition to engaging in the smart home and security service business. Vivint Smart Home is subject to federal and state laws related to consumer financing which may include rules related to fees and charges, disclosures and regulation of the party extending consumer credit.

1 The Cottonwood facility is located in Deweyville, Texas, but operates in the MISO market

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Energy Regulatory Matters

As participants in wholesale and retail energy markets and owners and operators of power plants, certain NRG entities are subject to regulation by various federal, state and provincial agencies. These include the CFTC, FERC, and the PUCT, as well as other public utility commissions in certain states where NRG's generation or distributed generation assets are located. In addition, NRG is subject to the market rules, procedures and protocols of the various ISO and RTO markets in which it participates. These power markets are subject to ongoing legislative and regulatory changes that may impact NRG's wholesale and retail operations. NRG must also comply with the mandatory reliability requirements imposed by NERC and the regional reliability entities in the regions where NRG operates.

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

Regional Regulatory Developments

NRG is affected by rule/tariff changes that occur in the ISO regions. For further discussion on regulatory developments see Item 15 — Note 24, Regulatory Matters, to the Consolidated Financial Statements.

Texas

Public Utility Commission of Texas’s Actions with Respect to Wholesale Pricing and Market Design — The PUCT continues to analyze and implement multiple options for promoting increased reliability in the wholesale electric market, including the adoption of a reliability standard for resource adequacy and market-based mechanisms to achieve this standard. During the 88th Regular Session, the Texas Legislature authorized deployment of the Performance Credit Mechanism ("PCM"), which will measure real-time contribution to system reliability and provide compensation for resources to be available, subject to certain "guardrails" such as an annual net cost cap, as part of its adoption of the PUCT Sunset Bill (House Bill 1500). The Texas Legislature also directed the PUCT to implement additional market design changes such as the creation of a new ancillary service called Dispatchable Reliability Reserve Service ("DRRS") to further increase ERCOT's capability to manage net load variability and firming requirements for new generation resources which penalize poor performance during periods of low grid reserves. The PUCT directed ERCOT to implement DRRS as a standalone product which will delay implementation until late 2025 or 2026. Additionally, through Senate Bill 2627, the Texas Legislature created the Texas Energy Fund, which received voter approval in November 2023, and will provide grants and low-interest loans to incentivize the development of more dispatchable generation and smaller backup generation in ERCOT. The PUCT has initiated a rulemaking proceeding to establish the process by which the Texas Energy fund loan proceeds will be distributed. A final rule creating the general structure of the loan program is expected to be adopted in March 2024.

Operating Reserve Demand Curve ("ORDC") — On August 3, 2023, the PUCT approved implementation of an enhancement to the ORDC as a bridge solution that was recommended by the ERCOT Technical Advisory Committee and the ERCOT board of directors. The ORDC enhancement will install price floors of $10 and $20 at reserve levels of 7,000 MW and 6,500 MW or below, respectively. ERCOT completed implementation on November 1, 2023.

Ruling on Pricing during Winter Storm Uri — On March 17, 2023, the Third Court of Appeals issued a ruling in Luminant Energy Co. v. PUCT, which is an appeal relating to the validity of two orders issued by the PUCT on February 15 and 16, 2021, respectively, governing scarcity pricing in the ERCOT wholesale electricity market during Winter Storm Uri. The Third Court found that the PUCT exceeded its statutory authority by ordering the market price of energy to be set at the high system wide offer cap due to scarcity conditions as a result of firm load shed occurring in ERCOT. The Third Court reversed the PUCT's orders and remanded the case. On March 23, 2023, the PUCT filed a petition for review to the Supreme Court of Texas seeking reversal of the Third Court's decision, which was granted on September 29, 2023. The Court received briefing on the merits and oral arguments occurred on January 30, 2024. The outcome of this appeal could potentially require a retroactive repricing of the ERCOT market prices during the subject time period.

Voluntary Mitigation Plan ("VMP") Changes — On March 13, 2023, the PUCT Staff determined that a portion of NRG's VMP should be terminated due to the increase in procurement of ancillary services by ERCOT, specifically non-spin reserve services, following Winter Storm Uri. As such, PUCT Staff terminated part of the VMP for NRG which provides protection from wholesale market power abuse accusations related to offers for ancillary services. NRG agreed with these changes to the VMP. At the March 23, 2023 open meeting, the PUCT approved the amended VMP. On February 23, 2024, NRG filed a notice of intent with the PUCT to terminate its existing VMP as of March 1, 2024.

ERCOT Request for Proposals for Winter Capacity — On October 2, 2023, ERCOT issued a Request for Proposals for Capacity ("RFP") for Winter 2023-2024. Proposals were due in early November to provide capacity for the December 1, 2023 to February 29, 2024 period. The RFP requirements were limited to demand response resources that have not participated in ERCOT or price responsive products. Ultimately, ERCOT cancelled the procurement due to lack of participation by qualified participants.

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Lubbock, Texas Transition to Competition — The customers of Lubbock Power and Light ("LP&L"), a municipally owned utility, will enter the Texas retail competitive market in March 2024. Starting in January 2024, LP&L customers can shop for a REP. Customers who do not select a REP by February 15, 2024 will be assigned to one of three default REPs, one of which is Reliant. LP&L customers will start transitioning to their chosen REP or a default REP on March 4, 2024.

PJM

Revisions to PJM Local Deliverability Area Reliability Requirement — The Base Residual Auction for the 2024/2025 delivery year commenced on December 7, 2022 and closed on December 13, 2022. On December 19, 2022, PJM announced that it would delay the publication of the auction results. On December 23, 2022, PJM made a filing at FERC to revise the definition of Locational Deliverability Area Reliability Requirement in the Tariff. This would allow PJM to exclude certain resources from the calculation of the Local Deliverability Area Reliability Requirement. On February 21, 2023, FERC accepted PJM's filing. Multiple parties, including NRG, filed for rehearing. Rehearing was denied by operation of law, and multiple parties, including the Company, filed appeals to the Third Circuit Court of Appeals. The price of the auction cleared significantly lower as a result of the PJM Tariff change.

Capacity Performance Penalties and Bonuses from Winter Storm Elliott — PJM experienced approximately 23 hours of Capacity Performance events from December 23-24, 2022 across PJM's entire footprint. The Company is subject to penalty and bonus payments related to the events. On April 3, 2023, FERC approved PJM's request to allow Winter Storm Elliott penalty payments to be spread over 9 months (with interest) and allow future penalties to have a 9 month window to be satisfied without interest. Multiple generators filed various complaints against PJM at FERC alleging that PJM violated its Tariff in, among other things, the manner in which it operated the system during Winter Storm Elliott and the resulting assessment of capacity performance penalties. On June 5, 2023, FERC issued an order setting the various complaints for settlement. A settlement in principle was filed with FERC on September 29, 2023 and was approved on December 19, 2023.

PJM Base Residual Auction Revisions and Delay — On April 11, 2023, PJM filed, and FERC subsequently approved, to delay the Base Residual Auctions for the 2025/2026 to 2028/2029 delivery years. On October 13, 2023, PJM made two filings proposing to develop market reforms to improve the operation of the capacity market through changes to the Market Seller Offer Cap rules, changes to PJM's resource adequacy risk modeling and capacity accreditation processes, and changes to capacity performance enhancements. On January 30, 2024, FERC accepted certain reforms to PJM's resource adequacy risk modeling and accreditation processes; on February 6, 2024, FERC rejected PJM's proposed changes to certain Market Seller Offer Cap rules and capacity performance enhancements. The approved changes will be in effect for the 2025/2026 Base Residual Auction scheduled to occur in July 2024, and will impact both demand and supply characteristics.

PJM Files to Make Changes to the Performance Assessment Interval Trigger — On May 30, 2023, PJM filed proposed tariff revisions at FERC that narrow the definition of Emergency Actions used to determine Performance Assessment Intervals ("PAIs"). On July 28, 2023, FERC accepted the tariff revisions, and PJM made its compliance filing on August 28, 2023. The new definition narrows the instances of when PAIs can occur and therefore decrease the instances of when capacity performance penalties are assessed.

Independent Market Monitor Market Seller Offer Cap Complaint — On March 18, 2021, finding that the calculation of the default Market Seller Offer Cap was unjust and unreasonable, FERC issued an Order, which permitted the PJM May 2021 capacity auction for the 2022/2023 delivery rule to continue under the existing rules and set a procedural schedule for parties to file briefs with possible solutions. On September 2, 2021, FERC issued an order in response to a complaint filed by the PJM Independent Market Monitor's proposal, which eliminated the Cost of New Entry-based Market Seller Offer Cap, implemented a limited default cap for certain asset classes based on going-forward costs and provided for unit specific cost review by the Independent Market Monitor for all other non-zero offers into the auctions. On October 4, 2021, as required by the Order, PJM submitted its compliance tariff and certain parties filed a motion for rehearing, which was denied by operation of law. On February 18, 2022, FERC addressed the arguments raised on rehearing and rejected the rehearing requests. Multiple parties filed appeals at the Court of Appeals for the D.C. Circuit, and on August 15, 2023, the Court denied the petitions for review. On January 12, 2024, the generator trade association filed a petition for review with the U.S. Supreme Court to overturn the August 15, 2023 judgment.

California

California Resource Planning Proceedings — As part of the Integrated Resource Procurement docket, the CPUC is requiring that all LSEs procure a pro rata share of 15.5 GW of new non-fossil resource adequacy ("RA") from 2023 to 2026. The new RA program rules adopted in 2023 are now in an implementation phase with a compliance process likely to be continually recalibrated through the first quarter of 2024. CPUC jurisdictional retail providers will be required to procure RA that meets their hourly load shape beginning in 2025. The result of these changes may create upward pressure on RA prices through 2024, and if LSEs cannot meet their RA obligations, penalties and restrictions on serving new customers may be issued. As relief to the tightness of the RA market, the CPUC adopted a final decision in December 2023 to extend PG&E's

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Diablo Canyon nuclear facility. The decision would allow the RA and GHG-free attributes of this 2-GW facility to be allocated to all LSEs to provide some relief to all LSEs' RA positions.

Other Regulatory Matters

From time to time, NRG entities may be subject to examinations, investigations and/or enforcement actions by federal, state and provincial licensing agencies and may face the risk of penalties for violation of financial services, consumer protections and other applicable laws and regulations.

Environmental Regulatory Matters

NRG is subject to numerous environmental laws in the development, construction, ownership and operation of power plants. These laws generally require that governmental permits and approvals be obtained before construction and maintained during operation of power plants. Federal and state environmental laws have become more stringent over time. Future laws may require the addition of emissions controls or other environmental controls or impose restrictions on the Company's operations including unit retirements. Complying with environmental laws often involves specialized human resources and significant capital and operating expenses, as well as occasionally curtailing operations. NRG decides to invest capital for environmental controls based on the relative certainty of the requirements, an evaluation of compliance options and the expected economic returns on capital.

A number of regulations that affect the Company have been and continue to be revised by the EPA, including requirements regarding coal ash, NAAQS revisions and implementation, and effluent limitation guidelines. NRG will evaluate the impact of these regulations as they are revised but cannot fully predict the impact of each until anticipated revisions and legal challenges are finally resolved.

Air 

The CAA and related regulations (as well as similar state and local requirements) have the potential to affect air emissions, operating practices and pollution control equipment required at power plants. Under the CAA, the EPA sets NAAQS for certain pollutants including SO2, ozone, and PM2.5. Many of the Company's facilities are located in or near areas that are classified by the EPA as not achieving certain NAAQS (non-attainment areas). The relevant NAAQS may become more stringent. On February 7, 2024, the EPA released a prepublication version of a final rule that when published in the Federal Register will increase the stringency of the PM2.5 NAAQS. The Company maintains a comprehensive compliance strategy to address continuing and new requirements. Complying with increasingly stringent air regulations could require the installation of additional emissions control equipment at some NRG facilities or retiring of units if installing such controls is not economic. Significant changes to air regulatory programs affecting the Company are described below.

CPP/ACE Rules — The attention in recent years on GHG emissions has resulted in federal and state regulations. In 2019, the EPA promulgated the ACE rule, which rescinded the CPP, which had sought to broadly regulate CO2 emissions from the power sector. On January 19, 2021, the D.C. Circuit vacated the ACE rule (but on February 22, 2021, at the EPA's request, stayed the issuance of the portion of the mandate that would vacate the repeal of the CPP). On June 30, 2022, the U.S. Supreme Court held that the "generation shifting" approach in the CPP exceeded the powers granted to the EPA by Congress. The Court did not address the related issues of whether the EPA may adopt only measures applied at each source. On May 23, 2023, the EPA proposed significantly revising the manner in which new and existing EGU's GHG emissions should be regulated including using hydrogen as a fuel, capturing and storing/sequestering CO2 and requiring new units to be more efficient. The EPA has stated that it intends to finalize these revisions in 2024. The Company expects that the final rule will be challenged in the courts and accordingly uncertain over the next several years.

Cross-State Air Pollution Rule ("CSAPR") — On March 15, 2023, the EPA signed and released a prepublication of a final rule that sought to significantly revise the CSAPR to address the good-neighbor obligations of the 2015 ozone NAAQS for 23 states after earlier having disapproved numerous state plans to address the issue. Several states, including Texas, challenged the EPA's disapproval of their state plans. On May 1, 2023, the United States Court of Appeals for the Fifth Circuit stayed the EPA's disapproval of Texas' and Louisiana's state plans, which disapprovals are a condition precedent to the EPA imposing its plan on Texas and Louisiana. Several other states are also similarly situated because of similar stays. Nonetheless, on June 5, 2023, the EPA published this rule in the Federal Register. On July 31, 2023, the EPA promulgated an interim final rule that addresses the various judicial orders that have stayed several State-Implementation-Plan disapprovals by limiting the effectiveness of certain requirements of the final rule promulgated on June 5, 2023 in Texas and five other states. The final rule decreases, over time, the ozone-season NOx allowances allocated to generators in the states not affected by the judicial stays beginning in 2023 by assuming that participants in this cap-and-trade program had or would optimize existing NOx controls and later install additional NOx controls. The Company cannot predict the outcome of the legal challenges to the: (i) various state disapprovals; (ii) the final rule promulgated on June 5, 2023; and (iii) the interim final rule promulgated on July 31, 2023 that seeks to address the judicial orders.

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Regional Haze Proposal — On May 2023, the EPA proposed to withdraw the existing Texas Sulfur Dioxide Trading Program and replace it with unit-specific SO2 limits for 12 units in Texas to address requirements to improve visibility at National Parks and Wilderness areas. If finalized as proposed, the rule would result in more stringent SO2 limits for two of the Company's coal-fired units in Texas. The Company cannot predict the outcome of this proposal.

Greenhouse Gas Emissions — NRG emits CO2 (and small quantities of other GHGs) when generating electricity at a majority of its facilities. Nearly all of NRG's domestic GHG emissions are subject to federal (U.S. EPA) GHG reporting requirements.

NRG's climate goals are to reduce greenhouse gas emissions by 50% by 2025, from its current 2014 base year, and to achieve net-zero emissions by 2050. Greenhouse gas emissions included in NRG's goals are directly controlled emissions, emissions from purchased electricity for NRG's consumption and emissions from employee business travel. In March 2021, the Science Based Targets initiative validated NRG's 2025 and 2050 goals as aligned with a 1.5 degree Celsius trajectory. This validation was based on NRG’s business in 2020, prior to its acquisition of Direct Energy and Vivint. Following the acquisitions, the magnitude of NRG’s indirect emissions changed, and the Company is currently in the process of analyzing these emissions.

From the current 2014 base year through 2023, the Company's directly controlled CO2e emissions decreased from 58 million metric tons to 24 million metric tons, representing a cumulative 58% reduction. The decrease is attributed to reductions in fleet-wide annual net generation and an overall market-driven shift away from coal as a primary fuel to natural gas. The achievement of NRG's 2025 emissions reduction targets could be impacted by volatility within the power markets, driven by market conditions and changes in regulatory policies.

As of December 31, 2023, less than 5% of the Company's consolidated revenues were derived from coal-fired operating assets.

The following charts reflect the Company’s domestic generation portfolio, including leased facilities and those accounted for through equity method investments, but excluding the battery storage and remaining renewables activity. Prior year information on U.S. CO2e emissions and U.S. generation was adjusted to remove divested assets.

Byproducts

In 2015, the EPA finalized a rule regulating byproducts of coal combustion (e.g., ash and gypsum) as solid wastes under the RCRA. On August 21, 2018, the D.C. Circuit found, among other things, that the EPA had not adequately regulated unlined ponds and legacy surface impoundments. On August 28, 2020, the EPA finalized "A Holistic Approach to Closure Part A: Deadline to Initiate Closure," which amended the April 2015 Rule to address the August 2018 D.C. Circuit decision and extend some of the deadlines. On November 12, 2020, the EPA finalized "A Holistic Approach to Closure Part B: Alternative Demonstration for Unlined Surface Impoundments," which further amended the April 2015 Rule to, among other things, provide procedures for requesting approval to operate existing ash impoundments with an alternate liner. On May 23, 2023, the EPA proposed establishing requirements for: (i) inactive (or legacy) surface impoundments at inactive facilities and (ii) all CCR management units (regardless of how or when the CCR was placed) at regulated facilities. NRG anticipates further rulemaking related to legacy surface impoundments and the Federal Permit Program.

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Domestic Site Remediation Matters

Under certain federal, state and local environmental laws, a current or previous owner or operator of a facility, including an electric generating facility, may be required to investigate and remediate releases or threatened releases of hazardous or toxic substances or petroleum products. NRG may be responsible for property damage, personal injury and investigation and remediation costs incurred by a party in connection with hazardous material releases or threatened releases. These laws impose liability without regard to whether the owner knew of or caused the presence of the hazardous substances, and the courts have interpreted liability under such laws to be strict (without fault) and joint and several. Cleanup obligations can often be triggered during the closure or decommissioning of a facility, in addition to spills during its operations.

Jewett Mine Lignite Contract — The Company's Limestone facility historically burned lignite obtained from the Jewett mine. Active mining ceased as of December 31, 2016; however, the Company remains responsible for reclamation activities and is responsible for all reclamation costs. NRG has recorded an adequate ARO liability. The Railroad Commission of Texas has imposed a bond obligation of approximately $112 million for the reclamation of the Jewett mine, which NRG supports through surety bonds. The cost of the reclamation may exceed the value of the bonds. NRG may provide additional performance assurance if required by the Railroad Commission of Texas.

Water 

The Company is required under the CWA to comply with intake and discharge requirements, requirements for technological controls and operating practices. As with air quality regulations, federal and state water regulations have become more stringent and imposed new requirements.

Effluent Limitations Guidelines — In 2015, the EPA revised the Effluent Limitations Guidelines ("ELG") for Steam Electric Generating Facilities, which imposed more stringent requirements (as individual permits were renewed) for wastewater streams from FGD, fly ash, bottom ash and flue gas mercury control. On September 18, 2017, the EPA promulgated a final rule that, among other things, postponed the compliance dates to preserve the status quo for FGD wastewater and bottom ash transport water by two years to November 2020 until the EPA amended the rule. On October 13, 2020, the EPA amended the 2015 ELG rule by: (i) altering the stringency of certain limits for FGD wastewater; (ii) relaxing the zero-discharge requirement for bottom ash transport water; and (iii) changing several deadlines. In October 2021, NRG informed its regulators that the Company intends to comply with the ELG by ceasing combustion of coal by the end of 2028 at its domestic coal units outside of Texas, and installing appropriate controls by the end of 2025 at its two plants that have coal-fired units in Texas. On March 29, 2023, the EPA proposed revisions to the ELG and sought comments, which the EPA is analyzing.

Regional Environmental Developments

Ash Regulation in Illinois — On July 30, 2019, Illinois enacted legislation that required the state to promulgate regulations regarding coal ash at surface impoundments. On April 15, 2021, the state promulgated the implementing regulation, which became effective on April 21, 2021. NRG has applied for initial operating permits and construction permits (for closure and retrofits) as required by the regulation and is waiting for permits to be issued by the Illinois EPA.

Houston Nonattainment for 2008 Ozone Standard — During the fourth quarter of 2022, the EPA changed the Houston area’s classification from Serious to Severe nonattainment for the 2008 Ozone Standard. Accordingly, Texas is required to develop a new control strategy and submit it to the EPA, which is expected by May 2024.

Customers

NRG sells to a wide variety of customers, primarily end-use customers in the residential, commercial and industrial, and wholesale sectors. The Company owns and operates power plants to generate and sell power to wholesale customers, such as utilities and other intermediaries. The Company had no customer that comprised more than 10% of the Company's consolidated revenues for the year ended December 31, 2023.

Human Capital

As of December 31, 2023, NRG and its consolidated subsidiaries had 18,131 employees, including 5,187 active smart home direct sales and installation individuals, which are largely seasonal. Approximately 4% of the Company's employees were covered by U.S. collective bargaining agreements. During 2023, the Company did not experience any labor stoppages or labor disputes at any of its facilities.

NRG believes its employees are vital to its success and is committed to offering employees a rewarding career that provides opportunities for growth and the ability to make valuable contributions toward the achievement of the Company’s business objectives. NRG focuses on safety, health and wellness, diversity, equity and inclusion, talent development and total rewards for its employees.

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Safety

Safety is embedded in the culture at NRG. The Company strives to begin meetings with a safety moment and regularly reminds its employees that safety comes first. NRG has achieved its targeted top decile safety record of Occupational Safety and Health Administration recordable injury rates in each of the 5 previous years.

The following chart reflects the Company's 5 year safety record, excluding Vivint Smart Home which uses different industry specific safety benchmarks.

Health and Wellness

For several years, NRG has invested in the health and well-being of its employees and their families. NRG provides programs that holistically support its employees’ physical, emotional and financial wellness, allowing employees the opportunity to take control of their well-being and focus on what matters most to them for a healthy, secure future.

For the 2023 plan year, the Company included well-being goals in the Annual Incentive Plan (AIP), ensuring participants are motivated to improve their physical, emotional and financial well-being.

Diversity, Equity and Inclusion

NRG is committed to diversity, equity and inclusion (DE&I) as an integral way the Company operates. In 2023, NRG completed a gender and race pay equity study to analyze the Company's pay decisions in light of gender, race, or other similar factors. The study demonstrated equitable pay practices after accounting for job level, experience, tenure and location. The Company first conducted this study in 2020 and committed to conduct the study every three years. In 2023, Forbes and Statista recognized NRG as one of The Best Employers for Diversity. Also in 2023, NRG created designated reflection rooms in its headquarters to accommodate religious practices and reflection. NRG held its first Lunar New Year's celebrations hosted by VIVIDH, the Company's Asian American Pacific Islander Business Resource Group. The Company also hosted its inaugural listening session in recognition of Canada's National Day for Truth and Reconciliation sponsored by RISE, its Indigenous Communities Business Resource Group.

Talent Development

NRG deploys various talent development strategies and programs with the goal of ensuring a pipeline of leadership that can execute on the Company’s strategy and drive value for all stakeholders. The Board of Directors regularly engages with management on leadership development and succession planning, including providing feedback on development plans and bench strength for key senior leader positions. The Board of Directors also has a structured program that allows directors to interact directly with individuals deeper within the organization whom management, through a robust talent assessment program, as well as mentoring relationships, has identified as high potential future leaders. In 2021, the Company launched an annual Emerging Leaders Program to strengthen the identified pipeline of future leaders and create a cohort of high potential candidates for leadership positions. In 2023, the Company launched a front-line leader program called Peak Leadership with the intent to onboard first-level leaders into their leadership role in select business units and is planning to expand its impact in 2024. The Company has a performance management tool that emphasizes a continuous feedback loop and a robust online training curriculum with topics including leadership, communication and productivity.

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Total Rewards

NRG seeks to provide market competitive compensation and benefits, benchmarked against direct peers, industry, and, where appropriate, general peers. To ensure incentives are properly aligned with business needs and can attract and retain qualified employees, the Compensation Committee of the Board of Directors actively reviews the Company's total rewards programs, including benchmarking programs against peer groups, assessing the risks of programs and evaluating the design of the short-term and long-term incentive programs. NRG continues to evaluate its benefits and offerings taking into consideration the needs of its employees to ensure they are competitive and best serve its employees. Every two years, the Company engages an independent third-party to benchmark its compensation and benefits programs against its peers and report the results to the Compensation Committee of the Board of Directors.

For further discussion and recent available data regarding the Company’s efforts and programs please see the Company’s 2023 Proxy Statement and 2022 Sustainability Report, which are available on the Company’s website at: www.nrg.com. Information included in these documents is not intended to be incorporated into this Form 10-K.

Available Information

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

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Item 1A — Risk Factors

NRG's risk factors are grouped into the following categories: (i) Risks Related to the Acquisition of Vivint Smart Home; (ii) Risks Related to the Operation of NRG's Business; (iii) Risks Related to Governmental Regulation and Laws; and (iv) Risks Related to Economic and Financial Market Conditions, and the Company's Indebtedness.

Risks Related to the Acquisition of Vivint Smart Home

The acquisition of Vivint Smart Home may not achieve its intended results and its integration may disrupt or have a negative impact on the Company’s business.

Achieving the anticipated cost savings and operating efficiencies from the acquisition of Vivint Smart Home is subject to risks, including whether the businesses of NRG and Vivint Smart Home are integrated in an efficient and effective manner. These risks include, but are not limited to:

•the difficulty of managing and integrating Vivint Smart Home and its operations;

•difficulties in implementing and maintaining uniform processes, systems, standards, controls, procedures, practices, policies and compensation standards;

•unanticipated issues in integrating information technology, communications, and other systems;

•the possibility of faulty assumptions underlying expectations regarding the integration process;

•the potential difficulty in managing an increased number of locations and employees;

•difficulty addressing any possible differences in corporate cultures and management philosophies; and

•the effect of any government regulations which relate to the business acquired.

Many of these factors are outside of the Company’s control. Failure to address these risks effectively could result in increased costs, lower-than-expected revenues or income generated by the combined company and diversion of management's time and energy and could have an adverse effect on the Company's business, financial results and prospects.

Risks Related to the Operation of NRG's Business

NRG's financial performance may be impacted by price fluctuations in the retail and wholesale power and natural gas markets, as well as fluctuations in coal and oil markets and other market factors that are beyond the Company's control.

Market prices for power, capacity, ancillary services, natural gas, coal, oil and renewable energy credits are unpredictable and tend to fluctuate substantially. Electric power generally must be produced concurrently with its use. As a result, power prices are subject to significant volatility due to supply and demand imbalances, especially in the day-ahead and spot markets. Long and short-term power and gas prices may also fluctuate substantially due to other factors outside of the Company's control, including:

•changes in generation capacity in the Company’s markets, including the addition of new supplies of power as a result of the development of new plants, expansion of existing plants, the continued operation of uneconomic power plants due to state subsidies, retirement of existing plants or addition of new transmission capacity;

•electric supply disruptions, including plant outages and transmission disruptions;

•changes in power and gas transmission infrastructure;

•transportation capacity constraints or inefficiencies;

•weather conditions, including extreme weather conditions and seasonal fluctuations, including the effects of climate change;

•changes in commodity prices and the supply of commodities, including but not limited to natural gas, coal and oil;

•changes in the demand for power or gas, or in patterns of power or gas usage, including the potential development of demand-side management tools and practices, distributed generation, and more efficient end-use technologies;

•development of new fuels, new technologies and new forms of competition for the production of power;

•economic and political conditions;

•changes in law, including judicial decisions, environmental regulations and environmental legislation; and

•federal, state and provincial power regulations and legislation, and regulations and actions of the ISO and RTOs.

While retail rates are generally designed to allow retail sellers of electricity and natural gas to pass through price fluctuations and other changes to costs, the Company may not be able to pass through all such changes to customers. For example, serving retail power customers in ISOs that have a capacity market exposes the Company to the risk that capacity costs can change and may not be recoverable, or the Company may engage in sales of power at fixed prices. Additionally, increases in wholesale costs to retail customers may cause additional customer defaults or increased customer attrition, or may be impacted by regulatory rules.

Further, in low natural gas price environments, natural gas can be the more cost-competitive fuel compared to coal for generating electricity. The Company enters into guaranteed supply contracts to provide for the amount of coal needed to operate its base load coal-fired generating facilities. The Company may experience periods where it holds excess amounts of coal if fuel

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pricing results in the Company reducing or idling coal-fired generating facilities. In addition, the Company may incur costs to terminate supply contracts for coal in excess of its generating requirements.

Such factors and the associated fluctuations in power prices have affected the Company's wholesale and retail profitability in the past and are expected to continue to do so in the future.

Volatile power and gas supply costs and demand for power and gas could adversely affect the financial performance of NRG's retail operations.

The Company's earnings and cash flows could be adversely affected in any period in which the wholesale power or gas prices rise at a greater rate than the rates the Company can charge to customers. The price of wholesale electricity and gas supply purchases associated with the retail operations' energy commitments can be different than that reflected in the rates charged to customers due to, among other factors:

•varying supply procurement contracts used and the timing of entering into related contracts;

•subsequent changes in the overall price of natural gas;

•daily, monthly or seasonal fluctuations in the price of natural gas relative to the 12-month forward prices;

•transmission and transportation constraints and the Company's ability to move power or gas to its customers; and

•changes in market heat rate (i.e., the relationship between power and natural gas prices).

The Company's earnings and cash flows could also be adversely affected in any period in which its customers' actual usage of electricity or gas significantly varies from the forecasted usage, which could occur due to, among other factors, weather events, changes in usage patterns, competition and economic conditions.

NRG's trading operations and use of hedging agreements could result in financial losses that negatively impact its results of operations, and NRG's hedging activities may increase the volatility in the Company's quarterly and annual financial results.

The Company typically enters into hedging agreements, including contracts to purchase or sell commodities at future dates and at fixed prices, to manage the commodity price risks inherent in its business. The Company’s risk management policies and hedging procedures may not mitigate risk as planned, and the Company may fail to fully or effectively hedge its commodity supply and price risk. In addition, these activities, although intended to mitigate price volatility, expose the Company to other risks. When the Company sells or buys power or gas forward, it gives up the opportunity to buy or sell at the future price, which not only may result in lost opportunity costs but also may require the Company to post significant amounts of cash collateral or other credit support to its counterparties. The Company also relies on counterparty performance under its hedging agreements and is exposed to the credit quality of its counterparties under those agreements. Further, if the values of the financial contracts change in a manner that the Company does not anticipate, or if a counterparty fails to perform under a contract, it could harm the Company's business, operating results or financial position.

NRG does not typically hedge the entire exposure of its operations against commodity price volatility. To the extent it does not hedge against commodity price volatility, the Company's results of operations and financial position may be improved or diminished based upon movement in commodity prices.

NRG may engage in trading activities, including the trading of power, natural gas, fuel, emissions allowances, environmental attributes and credits, weather, and other physical and financial commodity related products that are not directly related to the operation of the Company's generation facilities or the management of related risks. These trading activities take place in volatile markets and some of these trades could be characterized as speculative. This trading activity may expose the Company to the risk of significant financial losses which could have a material adverse effect on its business and financial condition.

NRG generally attempts to balance its fixed-price physical and financial purchases and sales commitments in terms of contract volumes and the timing of performance and delivery obligations through the use of financial and physical derivative contracts. These derivatives are accounted for in accordance with the FASB ASC 815, Derivatives and Hedging ("ASC 815"), which requires the Company to record all derivatives on the balance sheet at fair value with changes in the fair value resulting from fluctuations in the underlying commodity prices immediately recognized in earnings, unless the derivative qualifies for cash flow hedge accounting treatment or a scope exception. As a result, the Company's quarterly and annual results are subject to significant fluctuations caused by changes in market prices.

Competition may have a material adverse effect on NRG's results of operations, cash flows and the market value of its assets.

The Company's retail operations face competition for customers. Competitors may offer different products, lower prices, and other incentives which may attract customers away from the Company. In some retail electricity markets, the principal competitor may be the incumbent utility. The incumbent utility often has the advantage of long-standing relationships with its customers and strong brand recognition. Furthermore, NRG may face competition from other energy service providers, other

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energy industry participants, or nationally branded providers of consumer products and services, who have, and may in the future, develop businesses and offerings that compete with NRG.

The Company's smart home services market faces competition from residential security companies as well as other companies that are able to bundle their existing offerings, such as cable, telecommunications and internet service, with automation and monitored security services, and from do-it-yourself smart home systems, which customers are able to install without subscription services.

The Company’s plant operations face competition from newer or more efficient plants owned by competitors, which may put some of the Company's plants at a disadvantage to the extent these competitors are able to consume the same or less fuel as the Company's plant. Over time, the Company's plants may be unable to compete with these more efficient plants, which could result in asset retirements.

NRG’s competitors may have greater liquidity, greater access to credit and other financial resources, lower cost structures, more effective risk management policies and procedures, greater ability to incur losses, longer-standing relationships with customers, greater brand awareness, greater potential for profitability from retail sales or greater flexibility in the timing of their sale of generation capacity and ancillary services than NRG does. Competitors may also have better access to subsidies or other out-of-market payments that put NRG at a competitive disadvantage.

NRG's competitors may be able to respond more quickly to new laws or regulations or emerging technologies, or devote greater resources to marketing of retail energy and home services than NRG can. In addition, current and potential competitors may make strategic acquisitions or establish cooperative relationships among themselves or with third parties. Accordingly, it is possible that new competitors or alliances among current and new competitors may emerge and rapidly gain significant market share.

There can be no assurance that NRG will be able to compete successfully against current and future competitors, and any failure to do so would have a material adverse effect on the Company's business, financial condition, results of operations and cash flow.

NRG’s strategy relies, in part, on its ability to cross-serve and optimize its network of retail and Smart Home services customers, and if it is unable to retain existing customers and expand their use of the Company’s products and services, its expected growth and operating results could be adversely affected.

As part of NRG’s growth strategy, it is important for the Company to cross-sell energy sales and services to smart home services subscribers and smart home services to residential retail customers. As the Company continues pursuing cross-selling opportunities between these customers, there can be no assurances that its efforts in this regard will be successful. Additionally, for the Company to be successful in such cross-selling opportunities, it must retain its existing customers. The length of the terms for which NRG’s retail customers are contracted can be for multi-year periods, but many customers are contracted for a period of one year or less. Smart home services customers historically have entered into subscriptions that range from three to five years. These customers are not obligated to, and may not, renew their contracts or subscriptions after the expiration of their original commitments. If customers terminate their contracts, do not renew their contracts or do not expand their use of NRG’s products and services, the Company’s growth strategy may not be successful and its expected results of operations may be adversely affected.

NRG's costs, results of operations, financial condition and cash flows could be adversely impacted by disruption of its fuel supplies.

NRG relies on natural gas, coal and oil to fuel a majority of its power generation facilities. Grid operations depend on the continuing financial viability of contractual counterparties, as well as the infrastructure (including rail lines, rail cars, barge facilities, roadways, riverways and natural gas pipelines) available to serve generation facilities and to ensure that there is sufficient power produced to meet retail demand. As a result, the Company’s wholesale generation facilities are subject to the risks of disruptions or curtailments in the production of power at its generation facilities if no fuel is available at any price, if a counterparty fails to perform or if there is a disruption in the fuel delivery infrastructure.

NRG routinely hedges both its wholesale sales and purchases to support its retail load obligations. In order to hedge these obligations, the Company may enter into long-term and short-term contracts for the purchase and delivery of fuel. Many of the forward power sales contracts do not allow the Company to pass through changes in fuel costs or discharge the power sale obligations in the case of a disruption in fuel supply due to force majeure events or the default of a fuel supplier or transporter. Disruptions in the Company's fuel supplies or power supply arrangements may therefore require it to supply replacement power either by running its other, higher cost power plants or by obtaining power from third-party sources at market prices that could substantially exceed the contract price, or to pay damages to counterparties for failure to deliver power or sell electricity or natural gas as contracted. Any such event could have a material adverse effect on the Company's financial performance.

NRG also buys energy and fuel on a short-term or spot market basis. Prices sometimes rise or fall significantly over a relatively short period of time. The price NRG can obtain for the sale of energy may not rise at the same rate, or may not rise at

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all, to match a rise in fuel or delivery costs. Retail rates may also not rise at the same rate or may not rise at all. This may have a material adverse effect on the Company's financial performance.

NRG's plant operating characteristics and equipment, particularly at its coal-fired plants, often dictate the specific fuel quality to be combusted. The availability and price of specific fuel qualities may vary due to supplier financial or operational disruptions, transportation disruptions and force majeure. At times, coal of specific quality may not be available at any price or the Company may not be able to transport such coal to its facilities on a timely basis. In this case, the Company may not be able to run the coal facility even if it would be profitable. Operating a coal facility with different quality coal can lead to emission or operating problems. If the Company had sold forward the power from such a coal facility, it could be required to supply or purchase power from alternate sources, perhaps at a loss. This could have a material adverse impact on the financial results of specific plants and on the Company's results of operations.

There may be periods when NRG will not be able to meet its commitments under forward sale or purchase obligations at a reasonable cost or at all.

The Company may sell fixed price gas as a proxy for power. Because the obligations under most of the Company's forward sale agreements are not contingent on a unit being available to generate power, NRG is generally required to deliver power to the buyer, even in the event of a plant outage, fuel supply disruption or a reduction in the available capacity of the unit. To the extent that the Company does not have sufficient lower-cost capacity to meet its commitments under its forward sale obligations, the Company would be required to supply replacement power either by running its other, higher cost power plants or by obtaining power from third-party sources at market prices that could substantially exceed the contract price. If NRG fails to deliver the contracted power, it would be required to pay the difference between the market price at the delivery point and the contract price, and the amount of such payments could be substantial.

NRG may not have sufficient liquidity to hedge market risks effectively.

The Company is exposed to market risks through its retail and wholesale operations, which involve the purchase of electricity and natural gas for resale, the sale of energy, capacity and related products, and the purchase and sale of fuel, transmission services and emission allowances. These market risks include, among other risks, volatility arising from location and timing differences that may be associated with buying and transporting fuel, converting fuel into energy and delivering energy to a buyer.

NRG undertakes to hedge these market activities through agreements with various counterparties. Many of the Company's agreements with counterparties include provisions that require the Company to provide guarantees, offset or netting arrangements, letters of credit, a first lien on assets and/or cash collateral to protect the counterparties against the risk of the Company's default or insolvency. The amount of such credit support that must be provided typically is based on the difference between the price of the commodity in a given contract and the market price of the commodity. Significant movements in market prices can result in the Company being required to provide cash collateral and letters of credit in very large amounts. The effectiveness of the Company's strategy may depend on the amount of collateral available to enter into or maintain these contracts, and liquidity requirements may be greater than the Company anticipates or will be able to meet. Without a sufficient amount of working capital to post as collateral in support of performance guarantees or as a cash margin, the Company may not be able to manage price volatility effectively or to implement its strategy. An increase in the amount of letters of credit or cash collateral required to be provided to the Company's counterparties may negatively affect the Company's liquidity and financial condition.

Further, if retail customers use more power or gas than expected, or if any of NRG's facilities experience unplanned outages, the Company may be required to procure additional power or gas at spot market prices to fulfill contractual commitments. Without adequate liquidity to meet margin and collateral requirements, the Company may be exposed to significant losses, may miss significant opportunities, and may have increased exposure to the volatility of spot markets.

The operation of the Company's businesses is subject to advanced persistent cyber-based security threats and integrity risk. Attacks on NRG's infrastructure that breach cyber/data security measures could expose the Company to significant liabilities, reputational damage, regulatory action, and disrupt business operations, which could have a material adverse effect.

Numerous functions affecting the efficient operation of NRG’s businesses depend on the secure and reliable storage, processing and communication of electronic data and the use of sophisticated computer hardware and software systems, much of which is connected (directly or indirectly) to the internet. As a result, NRG's information technology systems and infrastructure, and those of its vendors and suppliers, are susceptible to cyber-based security threats which could compromise confidentiality, integrity or availability. While the Company has controls in place designed to protect its infrastructure, such breaches and threats are becoming increasingly sophisticated and complex, requiring continuing evolution of its program. Any such breach, disruption or similar event that impairs NRG's information technology infrastructure could disrupt normal business operations and affect the Company's ability to control its generation assets, provide smart home services, maintain

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confidentiality, availability and integrity of restricted data, access retail customer information and limit communication with third parties, which could have a material adverse effect on the Company.

As part of the continuing development of new and modified reliability standards, the FERC has approved changes to its Critical Infrastructure Protection reliability standards and has established standards for assets identified as "critical cyber assets." Under the Energy Policy Act of 2005, the FERC can impose penalties (up to $1 million per day, per violation) for failure to comply with mandatory electric reliability standards, including standards to protect the power system against potential disruptions from cyber/data and physical security breaches.

Further, the Company's retail, Home and Services businesses, as well as Vivint Smart Home's smart home platform, require accessing, collecting, storing and transmitting sensitive customer data in the ordinary course of business. Concerns about data privacy have led to increased regulation and other actions that could impact NRG's businesses and changes in data privacy and data protection laws and regulations or any failure to comply with such laws and regulations could adversely affect the Company's business and financial results. NRG's retail, Home, Services and Smart Home businesses may need to provide sensitive customer data to vendors and service providers who require access to this information in order to provide services, such as call center operations, to such businesses. The services and the networks and information systems utilized by the Company may be at risk for breaches as a result of third-party actions, employee or vendor error, malfeasance or other factors.

Although the Company takes precautions to protect its infrastructure, it has been, and will likely continue to be, subject to attempts at phishing and other cybersecurity intrusions. International conflict increases the risk of state-sponsored cyber threats and escalated use of cybercriminal and cyber-espionage activities. In particular, the current geopolitical climate has further escalated cybersecurity risk, with various government agencies, including the U.S. Cybersecurity & Infrastructure Security Agency, issuing warnings of increased cyber threats, particularly for U.S. critical infrastructure. While the Company has not experienced a cyber/data event causing any material operational, reputational or financial impact, it recognizes the growing threat within the general marketplace and the industry, and there is no assurance that NRG will be able to prevent any such impacts in the future. If a material breach of the Company's information technology systems were to occur, the critical operational capabilities and reputation of its business may be adversely affected, customer confidence may be diminished, and NRG may be subject to substantial legal or regulatory scrutiny and claims, any of which may contribute to potential legal or regulatory actions against the Company, loss of customers, fines, penalties or other sanctions and otherwise have a material adverse effect. Any loss or disruption of critical operational capabilities to support the Company's generation, commercial or retail operations, loss of customers, or loss of confidential or proprietary data through a breach, unauthorized access, disruption, misuse or disclosure could adversely affect NRG's reputation, expose the Company to material legal or regulatory claims and impair the Company's ability to execute its business strategy, which could have a material adverse effect. In addition, NRG may experience increased capital and operating costs to implement increased security for its information technology infrastructure. NRG cannot provide any assurance that such events and impacts will not be material in the future, and the Company's efforts to deter, identify and mitigate future breaches may require additional significant capital and may not be successful.

NRG relies on storage, transportation assets and suppliers, which it does not own or control, to deliver natural gas.

The Company depends on natural gas pipelines and other transportation and storage facilities owned and operated by third parties to deliver natural gas to wholesale and retail markets and to provide retail energy services to customers. The Company's ability to provide natural gas for its present and projected customers will depend upon its suppliers' ability to obtain and deliver supplies of natural gas, as well as NRG's ability to acquire supplies. Factors beyond the control of the Company and its suppliers may affect the Company's ability to deliver such supplies. These factors include other parties' control over the drilling of new wells and the facilities to transport natural gas to the Company's receipt points, development of additional interstate pipeline infrastructure, availability of supply sources competition for the acquisition of natural gas, priority allocations, impact of severe weather disruptions to natural gas supplies and the regulatory and pricing policies of federal and state regulatory agencies, as well as the availability of Canadian reserves for export to the U.S. Energy deregulation legislation may increase competition among natural gas utilities and impact the quantities of natural gas requirements needed for sales service. If supply, transportation or storage is disrupted, including for reasons of force majeure, the ability of the Company to sell and deliver its products and services may be hindered. As a result, the Company may be responsible for damages incurred by its customers, such as the additional cost of acquiring alternative supply at then-current market rates. These conditions could have a material impact on the Company's financial condition, results of operations and cash flows.

Operation of power generation facilities involves significant risks and hazards customary to the power industry that could have a material adverse effect on NRG's revenues and results of operations, and NRG may not have adequate insurance to cover these risks and hazards.

The ongoing operation of NRG's facilities involves risks that include the breakdown or failure of equipment or processes, performance below expected levels of output or efficiency and the inability to transport the Company's products to its customers in an efficient manner due to a lack of transmission capacity. Unplanned outages of generating units, including extensions of scheduled outages due to mechanical failures or other problems occur from time to time and are an inherent risk of the

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Company's business. Unplanned outages typically increase the Company's operation and maintenance expenses and may reduce the Company's revenues as a result of selling fewer MWh or incurring non-performance penalties and/or require NRG to incur significant costs as a result of obtaining replacement power from third parties in the open market or running one of its higher cost units to satisfy the Company's forward power sales obligations. NRG's inability to operate the Company's plants efficiently, manage capital expenditures and costs, and generate earnings and cash flow from the Company's asset-based businesses could have a material adverse effect on the Company's results of operations, financial condition or cash flows.

In addition, NRG provides plant operations and commercial services to a variety of third parties. There is a risk that mistakes, mis-operations or actions taken by these third parties could be attributed to NRG, including the risk of investigation or penalties being assessed to NRG in connection with the services it offers, or that regulators could question whether NRG had the appropriate safeguards in place.

Power generation involves hazardous activities, including acquiring, transporting and unloading fuel, operating large pieces of rotating equipment and delivering electricity to transmission and distribution systems. In addition to natural risks such as earthquake, flood, lightning, hurricane and wind, other hazards, such as fire, explosion, structural collapse and machinery failure are inherent risks in the Company's operations. These and other hazards can cause significant personal injury or loss of life, severe damage to and destruction of property, plant and equipment, contamination of, or damage to, the environment and suspension of operations. The occurrence of any one of these events may result in NRG being named as a defendant in lawsuits asserting claims for substantial damages, including for environmental cleanup costs, personal injury and property damage and fines and/or penalties.

NRG maintains an amount of insurance protection that it considers adequate, obtains warranties from vendors and obligates contractors to meet certain performance levels, but the Company cannot provide any assurance that these measures will be sufficient or effective under all circumstances and against all hazards or liabilities to which it may be subject. A successful claim for which the Company is not adequately insured or protected could hurt its financial results and materially harm NRG's financial condition. NRG cannot provide any assurance that its insurance coverage will continue to be available at all or at rates or on terms similar to those presently available. Any losses not covered by insurance could have a material adverse effect on the Company's financial condition, results of operations or cash flows.

Supplier and/or customer concentration, the inability of suppliers to meet their obligations and dependence on third-party service providers may expose the Company to significant financial credit or performance risks and adversely affect NRG's results of operations, cash flows and financial condition.

NRG often relies on a single contracted supplier or a small number of suppliers for the provision and transportation of fuel, chemicals and other services required for the operation of certain of its facilities. If these suppliers cannot perform these services, the Company utilizes the marketplace. There can be no assurance that the marketplace can provide these services as, when and where required or at comparable prices. The Company also relies on a number of sole or limited source suppliers for critical components for its smart home products and services, and those services are dependent on third-party cellular, telecommunications and/or internet providers.

The failure of any supplier or customer to fulfill its contractual obligations to NRG, the inability of NRG to source products and services on acceptable terms, if at all, and the failure of third parties to provide services to its customers that are necessary for the Company’s smart home services could have a material adverse effect on the Company's financial results. As a result, the financial performance of the Company's facilities is dependent on the credit quality of, and continued performance by, suppliers and customers, which cannot be guaranteed.

Maintenance, expansion and refurbishment of power generation facilities involve significant risks that could result in unplanned power outages or reduced output and could have a material adverse effect on NRG's results of operations, cash flows and financial condition.

NRG's facilities require periodic maintenance and repair. Any unexpected failure, including failure associated with breakdowns, forced outages or any unanticipated capital expenditures could result in reduced profitability. NRG cannot be certain of the level of capital expenditures that will be required due to changing environmental and safety laws (including changes in the interpretation or enforcement thereof), needed facility repairs and unexpected events (such as natural disasters or terrorist attacks). The unexpected requirement of large capital expenditures could have a material adverse effect on the Company's liquidity and financial condition.

NRG relies on power transmission and distribution facilities that it does not own or control and that are subject to transmission constraints within a number of the Company's core regions.

NRG depends on transmission and distribution facilities owned and operated by others to deliver power to its customers. If transmission or distribution is disrupted, including by force majeure events, or if the transmission or distribution infrastructure is inadequate, NRG's ability to deliver power may be adversely impacted. The Company also cannot predict

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whether transmission or distribution facilities will be expanded in specific markets to accommodate competitive access to those markets.

In addition, in certain of the markets in which NRG operates, energy transmission congestion may occur and the Company may be deemed responsible for congestion costs associated with power sales or purchases, or retail sales, particularly where the Company’s load is not co-located with its retail sales obligations. If NRG were liable for such congestion costs, the Company's financial results could be adversely affected.

Rates and terms for service of certain residential and commercial customers in Alberta are subject to regulatory review and approval.

The Company owns Direct Energy Regulated Services, which serves as a regulated rate supplier for residential and commercial energy customers in portions of the province of Alberta. It is required to engage in regulatory approval proceedings as a part of the process of establishing the terms and rates for sales of power and natural gas. These proceedings typically involve multiple parties, including governmental bodies and officials, consumer advocacy groups and various consumers of energy, who have differing concerns but also have the common objective of limiting rate increases or even reducing rates. Decisions are subject to appeal, potentially leading to additional uncertainty associated with the approval proceedings. The potential duration of such proceedings creates a risk that rates ultimately approved by the applicable regulatory body may not be sufficient for the Company to recover its costs by the time the rates become effective. Established rates are also subject to subsequent reviews by regulators, whereby various portions of rates could be adjusted, subject to refund or disallowed. In certain instances, the Company could agree to negotiated settlements related to various rate matters and other cost recovery elements. These settlements are subject to regulatory approval. The ultimate outcome and timing of regulatory rate proceedings have a significant effect on the Company to recover its costs or earn an adequate return. In addition, subsequent legislative or regulatory action could alter the terms on which the regulated business operates and future earnings could be negatively impacted. The Company also operates a competitive energy supply business in Alberta that is not subject to rate regulation and is subject to stringent requirements to segregate operations and information relating to the competitive business from the regulated business. Failure to comply with these and other requirements on the business could subject the Company's regulated and competitive businesses in Alberta to fines, penalties, and restrictions on the ability to continue business.

Because NRG owns less than a majority of the ownership interests of some of its project investments, the Company cannot exercise complete control over their operations.

NRG has limited control over the operation of some project investments and joint ventures because the Company's investments are in projects where it beneficially owns less than a majority of the ownership interests. NRG seeks to exert a degree of influence with respect to the management and operation of projects in which it owns less than a majority of the ownership interests by negotiating to obtain positions on management committees or to receive certain limited governance rights, such as rights to veto significant actions. However, the Company may not always succeed in such negotiations. NRG may be dependent on its co-venturers to operate such projects. The Company's co-venturers may not have the level of experience, technical expertise, human resources management or other attributes necessary to operate these projects optimally. The approval of co-venturers also may be required for NRG to receive distributions of funds from projects or to transfer the Company's interest in projects.

Future acquisition or disposition activities could involve unknown risks and may have materially adverse effects and NRG may be subject to trailing liabilities from businesses that it disposes of or that are inactive.

NRG may in the future acquire or dispose of businesses or assets, acquire or sell books of retail customers, or pursue other business activities, directly or indirectly, through subsidiaries that involve a number of risks. The acquisition of companies and assets, and their integration, is subject to substantial risks, including the failure to identify material problems during due diligence, the risk of over-paying for assets or customers, the inability to retain customers and the inability to arrange financing for an acquisition as may be required or desired. Further, the integration and consolidation of acquisitions requires substantial human, financial and other resources and, ultimately, the Company's acquisitions may not be successfully integrated. In the case of dispositions, such risks may relate to employment matters, counterparties, regulators and other stakeholders in the disposed business, the separation of disposed assets from NRG’s business, the management of NRG’s ongoing business, and other financial, legal and operational matters related to such disposition, which may be unknown to NRG at the time. In addition, NRG may be subject to material trailing liabilities from disposed businesses. Any such risk may result in one or more costly disputes or litigation. There can be no assurances that any future acquisitions will perform as expected or that the returns from such acquisitions will support the indebtedness incurred to acquire them or the capital expenditures needed to develop them. There can also be no assurances that NRG will realize the anticipated benefits from any such dispositions. The failure to realize the anticipated returns or benefits from an acquisition or disposition could adversely affect NRG's results of operations, cash flows and financial condition.

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Negative publicity may damage NRG's reputation or its brands and negatively impact its business, financial condition, results of operations and ability to attract and retain highly qualified employees.

NRG’s reputation and brands could be damaged for numerous reasons, including negative views of the Company’s environmental impact, sustainability goals, supply chain practices, product and service offerings, sponsorship relationships, charitable giving programs and public statements made by Company officials. Additionally, the Company is from time to time named in investigations, claims and lawsuits arising in the ordinary course of business, and customers have in the past communicated complaints to consumer protection organizations, regulators or the media. Negative claims or publicity regarding the Company or its operations, offerings, practices or customer service may damage its brands or reputation, even if such claims are untrue. The Company may also experience criticism or backlash from media, customers, employees, government entities, advocacy groups and other stakeholders that disagree with positions taken by the Company or its executives. If the Company’s brands or reputation are damaged, it could negatively impact the Company’s business, financial condition, results of operations, and ability to attract and retain highly qualified employees.

The Company has made investments focused on consumer products that may not be successful, may not achieve the intended financial results or may result in product liability and reputational risk that could adversely affect the Company.

The Company may be liable to customers for any damage caused to customers’ homes, facilities, belongings or property during the installation of Company products and systems, such as smart home systems, home back-up generators and residential HVAC system repairs, installation and replacements. Where such work is performed by independent contractors, such as repairs performed under the Company's home protection plan products, the Company may nonetheless face claims and costs for damage. In addition, shortages of skilled labor for Company projects could significantly delay a project or otherwise increase its costs. The products that the Company sells or manufactures may expose the Company to product liability claims relating to personal injury, death, or environmental or property damage, and may require product recalls or other actions. Although the Company maintains liability insurance and its service contracts limit Company liability, the Company cannot be certain that its coverage will be adequate for liabilities actually incurred or that insurance will continue to be available to the Company on economically reasonable terms, or at all, or that contractual limitations will be enforced. The laws of some states limit or prohibit insurance coverage for certain liabilities and actions, and any significant uninsured damages could have a material adverse effect on the Company’s business, financial condition and cash flows. Further, any product liability claims or damage caused by the Company could significantly impair the Company’s brand and reputation, which may result in a failure to maintain customers and achieve the Company’s desired growth initiatives in these new businesses.

Changes in technology may impair the value of, and the attractiveness of, its retail products, smart home services and NRG’s generation facilities.

Research and development activities are ongoing in the industry to provide alternative and more efficient technologies to produce power, including wind, photovoltaic (solar) cells, hydrogen, energy storage, and improvements in traditional technologies and equipment, such as more efficient gas turbines. Advances in these or other technologies, including through artificial intelligence, could reduce the costs of power production to a level below what the Company has currently forecasted, which could adversely affect its cash flows, results of operations or competitive position. Technology, including distributed technology or changes in retail rate structures, may also have a material impact on the Company’s ability to retain retail customers. Further, technological innovation and changes could cause the Company’s smart home products and services to become obsolete, or otherwise more expensive and less effective than those of competitors, putting the Company at a competitive disadvantage.

Some emerging technologies, such as distributed renewable energy technologies, broad consumer adoption of electric vehicles and energy storage devices, could affect the price of energy. These emerging technologies may affect the financial viability of utility counterparties and could have significant impacts on wholesale market prices, which could ultimately have a material adverse effect on NRG's financial condition, results of operations and cash flows.

The Company’s smart home services rely on intellectual property and any failure to adequately protect such intellectual property, or claims that the Company has infringed on others’ intellectual property rights, could have an adverse effect on its business and operations and result in a competitive disadvantage.

The Company relies on a combination of patent, trademark, copyright and trade secret laws of the United States and other countries and a combination of confidentiality procedures, contractual provisions and other methods, to protect its intellectual property, all of which offer only limited protection. If the Company fails to acquire the necessary intellectual property rights or adequately protect or assert its intellectual property rights, competitors may manufacture and market similar products and services or convert customers, which could adversely affect market share and results of operations for smart home services. In addition, patent rights may not prevent competitors from developing, using or selling products or services that are similar to or address the same market as the Company’s smart home products and services. Certain of the Company’s smart home solutions contain software modules licensed under “open-source” licenses, which may entail greater risks than the use of third-party commercial software, as open-source licensors generally do not provide warranties or other contractual protections regarding

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infringement claims or the quality of the code. Further, if proprietary software is combined with open-source software, in certain cases the Company could be required to release the source code of the proprietary software to the public, allowing competitors to create similar products with lower development effort and time.

It is possible that certain of the Company’s smart home products and services or those of third parties incorporated into its offerings could infringe the intellectual property rights of others. From time to time, Vivint Smart Home has been subject to claims based on allegations of infringement, misappropriation or other violations of the intellectual property rights of others. If the Company is unable to successfully defend against such claims or license necessary third-party technology or other intellectual property on acceptable terms it may be required to develop alternative, non-infringing technology, which could require significant time, effort, and expense and may ultimately not be successful.

NRG's business, financial condition and results of operations could be adversely impacted by strikes or work stoppages by its unionized employees or inability to replace employees as they retire.

As of December 31, 2023, approximately 4% of NRG's employees were covered by collective bargaining agreements. In the event that the Company's union employees strike, participate in a work stoppage or slowdown or engage in other forms of labor strife or disruption, NRG would be responsible for procuring replacement labor or the Company could experience reduced power generation or outages. Although NRG's ability to procure such labor is uncertain, contingency staffing planning is completed as part of each respective contract negotiation. Strikes, work stoppages or the inability to negotiate future collective bargaining agreements on favorable terms could have a material adverse effect on the Company's business, financial condition, results of operations and cash flows. In addition, a number of the Company's employees at NRG's plants are close to retirement. The Company's inability to replace retiring workers could create potential knowledge and expertise gaps as such workers retire.

NRG's failure to manage key executive succession and retention and to continue to attract qualified personnel could adversely affect the Company's financial condition and results of operations.

The loss of one or more of the Company’s key personnel or the inability to effectively identify a suitable successor to a key role could adversely affect the Company’s business. The failure to successfully transition and assimilate key employees, the effectiveness of the Company’s leaders, and any further transition, could adversely affect the Company’s financial condition and results of operations.

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

NRG's generation facilities and the facilities of third parties on which they rely may be targets of terrorist activities, as well as events occurring in response to or in connection with such activities, all of which could cause environmental repercussions and/or result in full or partial disruption of the facilities ability to generate, transmit, transport or distribute electricity or natural gas. Strategic targets, such as energy-related facilities, may be at greater risk of future terrorist activities than other domestic targets. Any such environmental repercussions or disruption could result in a significant decrease in revenues or significant reconstruction or remediation costs beyond what could be recovered through insurance policies, which could have a material adverse effect on the Company's financial condition, results of operations and cash flows. In addition, significant weather events or terrorist actions could damage or shut down the power or gas transmission and distribution facilities upon which the Company is dependent, which may reduce retail volume for extended periods of time. Power or gas supply may be sold at a loss if these events cause a significant loss of retail customer demand.

Risks Related to Governmental Regulation and Laws

NRG's business is subject to substantial energy regulation and may be adversely affected by legislative or regulatory changes, as well as liability under, or any future inability to comply with, existing or future energy regulations or requirements.

NRG's business is subject to extensive U.S. federal, state and local laws and foreign laws. Compliance with, or changes to, the requirements under these legal regimes may cause the Company to incur significant additional costs, reduce the Company's ability to hedge exposure or to sell retail power within certain states or to certain classes of retail customers, or restrict the Company’s marketing practices, its ability to pass through costs to retail customers, or its ability to compete on favorable terms with competitors, including the incumbent utility. Retail competition and home protection services are regulated on a state-by-state or at the province-by-province level and are highly dependent on state and provincial laws, regulations and policies, which could change at any moment. Failure to comply with such requirements could result in the shutdown of a non-complying facility or line of business, the imposition of liens, fines, and/or civil or criminal liability.

Public utilities under the FPA are required to obtain FERC acceptance of their rate schedules for wholesale sales of electricity. Except for ERCOT generation facilities and power marketers, all of NRG's non-qualifying facility generating companies and power marketing affiliates in the U.S. make sales of electricity in interstate commerce and are public utilities for

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purposes of the FPA. FERC has granted each of NRG's generating and power marketing companies that make sales of electricity outside of ERCOT the authority to sell electricity at market-based rates. FERC's orders that grant NRG's generating and power marketing companies market-based rate authority reserve the right to revoke or revise that authority if FERC subsequently determines that NRG can exercise market power in transmission or generation, create barriers to entry, or engage in abusive affiliate transactions. In addition, NRG's market-based sales are subject to certain market behavior rules, and if any of NRG's generating and power marketing companies were deemed to have violated those rules, they are subject to potential disgorgement of profits associated with the violation and/or suspension or revocation of their market-based rate authority. If NRG's generating and power marketing companies were to lose their market-based rate authority, such companies would be required to obtain FERC's acceptance of a cost-of-service rate schedule and could become subject to the accounting, record-keeping, and reporting requirements that are imposed on utilities with cost-based rate schedules. This could have a material adverse effect on the rates NRG charges for power from its facilities.

The Company's generation assets are also subject to the reliability standards promulgated by the designated Electric Reliability Organization (currently NERC) and approved by FERC. If NRG fails to comply with the mandatory reliability standards, NRG could be subject to sanctions, including substantial monetary penalties and increased compliance obligations. NRG is also affected by legislative and regulatory changes, as well as changes to market design, market rules, tariffs, cost allocations, and bidding rules that occur in the existing ISOs. The ISOs that oversee most of the wholesale power markets impose, and in the future may continue to impose, mitigation, including price limitations, offer caps, non-performance penalties and other mechanisms to address some of the volatility and the potential exercise of market power in these markets. These types of price limitations and other regulatory mechanisms may have a material adverse effect on the profitability of NRG's generation facilities that sell energy and capacity into the wholesale power markets.

The regulatory environment is subject to significant changes due to state and federal policies affecting wholesale and retail competition and the creation of incentives for the addition of large amounts of new renewable generation and, in some cases, transmission. These changes are ongoing, and the Company cannot predict the future design of the wholesale power markets or the ultimate effect that the changing regulatory environment will have on NRG's business. In addition, in some of these markets, interested parties have proposed material market design changes. If competitive restructuring of the electric power markets is reversed, discontinued, or delayed, the Company's business prospects and financial results could be negatively impacted. In addition, there have been a number of reforms to the regulation of the derivatives markets, both in the United States and internationally. These regulations, and any further changes thereto, or adoption of additional regulations, including any regulations relating to position limits on futures and other derivatives or margin for derivatives, could negatively impact NRG’s ability to hedge its portfolio in an efficient, cost-effective manner by, among other things, potentially decreasing liquidity in the forward commodity and derivatives markets or limiting NRG’s ability to utilize non-cash collateral for derivatives transactions.

NRG’s business may be affected by interference in the competitive wholesale marketplace.

NRG’s generation and competitive retail operations rely on a competitive wholesale marketplace. The competitive wholesale marketplace may be impacted by out-of-market subsidies, imports of power from Canada, renewable mandates or subsidies, mandates to sell power below its cost of acquisition and associated costs as well as out-of-market payments to new or existing generators. These out-of-market subsidies to existing or new generation undermine the competitive wholesale marketplace, which can lead to premature retirement of existing facilities, including those owned by the Company. If these measures continue, capacity and energy prices may be suppressed, and the Company may not be successful in its efforts to insulate the competitive market from this interference. The Company's retail operations may be materially impacted by rules or regulations that allow regulated utilities to participate in competitive retail markets or own and operate facilities that could be provided by competitive market participants.

Additions or changes in tax laws and regulations could potentially affect the Company’s financial results or liquidity.

NRG is subject to various types of tax arising from normal business operations in the jurisdictions in which the Company operates. Any additions or changes to tax legislation, or their interpretation and application, including those with retroactive effect, could have a material adverse effect on NRG’s financial condition and results of operations, including income tax provision and accruals reflected in the consolidated financial statements. Beginning in 2023, the Company is now subject to a 15% corporate alternative minimum tax as a result of the Inflation Reduction Act. The CAMT may lead to volatility in the Company’s cash tax payment obligations, particularly in periods of significant commodity or currency variability resulting from potential changes in the fair value of derivative instruments. The Company continuously monitors and assesses proposed tax legislation that could negatively impact its business.

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The Capacity Performance product into the PJM market could lead to substantial changes in capacity income and non-performance penalties, which could have a material adverse effect on NRG’s results of operations, financial condition and cash flows.

PJM operates a pay-for-performance model where capacity payments are modified based on real-time generator performance. Capacity market prices are sensitive to design parameters, as well as additions of new capacity. NRG may experience substantial changes in capacity income and incur non-performance penalties, which could have a material adverse effect on NRG’s results of operations, financial condition and cash flows.

NRG is subject to environmental laws that impose extensive and increasingly stringent requirements on the Company's ongoing operations, as well as potentially substantial liabilities arising out of environmental contamination. These environmental requirements and liabilities could adversely impact NRG's results of operations, financial condition and cash flows.

NRG is subject to the environmental laws of foreign and U.S., federal, state and local authorities. The Company must comply with numerous environmental laws and obtain numerous governmental permits and approvals to build and operate the Company's plants. Federal and state environmental laws generally have become more stringent over time. Should NRG fail to comply with any environmental requirements that apply to its operations, the Company could be subject to administrative, civil and/or criminal liability and fines, and regulatory agencies could take other actions seeking to curtail the Company's operations. In addition, when new requirements take effect or when existing environmental requirements are revised, reinterpreted or subject to changing enforcement policies, NRG's business, results of operations, financial condition and cash flows could be adversely affected.

NRG's businesses are subject to physical, market and economic risks relating to potential effects of climate change, and policies at the national, regional and state levels to regulate GHG emissions and mitigate climate change which could adversely impact NRG's results of operations, financial condition and cash flows.

Fluctuations in weather and other environmental conditions, including temperature and precipitation levels, may affect consumer demand for electricity or natural gas. In addition, the potential physical effects of climate change, such as increased frequency and severity of storms, floods and other climatic events, could disrupt NRG's operations and supply chain, and cause it to incur significant costs in preparing for or responding to these effects. These or other changes in climate could lead to increased operating costs or capital expenses. NRG's customers may also experience the potential physical impacts of climate change and may incur significant costs in preparing for or responding to these efforts, including changing the fuel mix and resiliency of their energy solutions and supply.

The contribution of climate change to the frequency or intensity of weather-related events could affect NRG's operations and planning process. Climate change could also affect the availability of a secure and economical supply of water in some locations, which is essential for the continued operation of NRG's generation plants. NRG monitors water supply risk carefully. If it is determined that a water supply risk exists that could impact projected generation levels at any plant, risk mitigation efforts are identified and evaluated for implementation.

Further, demand for NRG's energy-related services could be similarly impacted by consumers’ preferences or market or regulatory factors favoring energy efficiency, lower carbon energy sources or reduced electricity or natural gas usage.

NRG's GHG emissions reduction targets can be found in Item 1, Business —Environmental Regulatory Matters. The Company's ability to achieve these targets depends on many factors, including the ability to retire high emitting assets, ability to reduce emissions based on technological advances and innovation, and ability to source energy from less carbon intense resources. In addition, any future decarbonization efforts may increase costs, or NRG may otherwise be limited in its ability to apply them. The cost associated with NRG's GHG emissions reduction goals could be significant. Failure to achieve the Company's emissions targets could result in a negative impact on access to and cost of capital, changing investor sentiment regarding investment in the Company or reputation harm.

Enhanced data privacy and data protection laws and regulations or any non-compliance with such laws and regulations, could adversely affect NRG’s business and financial results.

The consumer privacy landscape continues to experience momentum for greater privacy protection and reform at the state and federal level in response to precedents set forth by the General Data Protection Regulation (the "GDPR") and the California Consumer Privacy Act (the "CCPA"). The development and evolving nature of domestic and international privacy regulation and enforcement could impact and potentially limit how NRG processes personally identifiable information. California residents now have increased access rights (including the right to limit the use and disclosure of sensitive personal information), which are enforced by a new state privacy regulator, resulting in more scrutiny of business practices and disclosures. Additional states including Virginia, Utah, Connecticut, Colorado, Nevada and Texas have similarly adopted enhanced data privacy legislation and patterned after the standards set forth by CCPA, including broader data access rights, with Virginia going a step further requiring businesses to perform data protection assessments for certain processing activities. The Company is also

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bound by contractual requirements relating to privacy and data protection, and may agree to additional contractual requirements addressing these matters from time to time.

As new laws and regulations are created, amended or expanded, requiring businesses to implement processes to enable customers access to their data and enhanced data protection and management standards, NRG cannot forecast with any certainty the impact that they may have on the Company’s business; however, it is possible the Company may find it necessary or desirable to change certain of its business practices or to expend resources to modify its home products and services and otherwise adapt to these changes. It is possible that the Company may be unable to make such changes and modifications in a commercially reasonable manner or at all, and its ability to develop new home services and features could be limited. Any non-compliance with laws may result in proceedings or actions against the Company by governmental entities or individuals. Moreover, any inquiries or investigations, government penalties or sanctions, or civil actions by individuals may be costly to comply with, resulting in negative publicity, increased operating costs, significant management time and attention, and may lead to remedies that harm the business, including fines, demands or orders that existing business practices be modified or terminated.

NRG's retail operations and smart home services are subject to changing rules and regulations that could have a material impact on the Company's profitability.

The competitiveness of NRG's retail operations partially depends on regulatory policies that establish the structure, rules, terms and conditions upon which services are offered to retail customers. These policies can include, among other things, controls on the retail rates that NRG can charge, the imposition of additional costs on sales, restrictions on the Company's sell certain types of products or ability to obtain new customers through various marketing channels and disclosure requirements. The Company's retail operations may be materially impacted by rules or regulations that allow regulated utilities to participate in competitive retail markets or own and operate facilities that could be provided by competitive market participants. Additionally, state, federal or provincial imposition of net metering or RPS programs can make it more or less expensive for retail customers to supplement or replace their reliance on grid power.

The Company’s smart home services focus on transactions with residential customers, subjecting it to a variety of laws, regulations and licensing requirements governing interactions with residential consumers, including those pertaining to privacy and data security, consumer financial and credit transactions, home improvements, warranties and door-to-door solicitation. In certain jurisdictions, the Company is required to obtain licenses or permits to comply with standards governing marketing and sales efforts, installation of equipment or servicing of subscribers, and monitoring station employee selection and training. Increased regulation of matters relating to interactions with residential consumers could require modification to the Company’s home services operations and the incurrence of additional expenses. Further, any expansion of the scope of products or services into new markets may require additional licenses and expenditures to otherwise maintain compliance with additional laws, regulations or licensing requirements. These laws and regulations, as well as their interpretation, and any new laws, regulations or licensing requirements could negatively affect the Company’s ability to acquire new residential customers. Any of these measures could increase costs for providing, or reduce customer satisfaction with respect to, smart home services.

The Federal Trade Commission ("FTC") and the Federal Communications Commission have issued regulations that restrict direct-to-home marketing, telemarketing, email marketing and other sales practices, including limitations on methods of communication, requirements to maintain a “do not call” list, cancellation rights and required training for personnel to comply with these restrictions. Any noncompliance, or alleged noncompliance, of applicable regulations by the Company, third-party vendors used for marketing, telemarketing or lead generation activities or independent, third-party authorized dealers of smart home services could result in private rights of actions or enforcement actions for civil or criminal penalties. Changes in regulations or interpretations that further restrict lead generating activities also could result in a reduction in the number of new smart home services customers.

The Company’s smart home business exposes it to risks of liability for the acts or omissions of its employees, including with respect to sales practices.

Activities in connection with sales efforts by employees, independent contractors, and other agents, including predatory door-to-door sales tactics and fraudulent misrepresentations, have in the past subjected it to, and could in the future subject the Company to, governmental investigations and class action lawsuits for, among others, false advertising and deceptive trade practice damage claims. Any litigation or regulatory proceedings resulting from such activities could adversely impact the Company’s business, financial condition, results of operations, and cash flows.

The Company is subject to various risks in connection with Vivint Smart Home’s ongoing settlement administration process involving the FTC, and may be subject to FTC Actions in the future.

In 2021, Vivint Smart Home entered into a settlement with the FTC where Vivint Smart Home paid a total of $20 million to the United States and agreed to implement various compliance-related measures. The settlement requires an initial assessment and thereafter biennial assessments by an independent third-party assessor of Vivint Smart Home’s compliance

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programs and for the assessor to provide a report to the FTC staff on ongoing compliance with the settlement. Although Vivint Smart Home took action to enhance its compliance programs, these and other measures that the Company may take in the future may not be successful. If any assessments identify deficiencies in the Company’s efforts to comply, and should the FTC determine that Vivint Smart Home is not in full compliance with the settlement, the FTC could take further action, such as seeking judicial remedies for any noncompliance, and Vivint Smart Home could be subject to additional sanctions and restrictions on its smart home operations. In addition, the filing of an application with the court for noncompliance with the settlement could lead to regulatory actions by other agencies or private litigation, which could impact Vivint Smart Home’s ability to obtain regulatory approvals necessary to carry out present or future plans and operations, and result in negative publicity.

The Company's international operations are exposed to political and economic risks, commercial instability and events beyond the Company's control in the countries in which it operates, which risks may negatively impact the Company's business.

The Company's international operations depend on products manufactured, purchased and sold in the U.S. and internationally. In some cases, these countries have greater political and economic volatility and greater vulnerability to infrastructure labor, and supply chain disruptions than in NRG's other markets. Operating a business in a number of different regions and countries exposes the Company to a number of risks, including: imposition of burdensome tariffs or quotas, multiple and potentially conflicting laws, regulations and policies that are subject to change, imposition of currency restrictions on repatriation of earnings or other restraints, national and international conflict, including terrorist acts and political and economic instability or civil unrest that may severely disrupt economic activity in affected countries and result in increased cost. The occurrence of one or more of these events may negatively impact the Company's business, results of operations and financial condition.

Risks Related to Economic and Financial Market Conditions and the Company's Indebtedness

NRG's level of indebtedness could adversely affect its ability to raise additional capital to fund its operations or return capital to stockholders. It could also expose it to the risk of increased interest rates and limit its ability to react to changes in the economy or its industry.

NRG's substantial amount of debt could have negative consequences, including:

•increasing NRG's vulnerability to general economic and industry conditions;

•requiring a substantial portion of NRG's cash flow from operations be used to pay principal and interest on its indebtedness, which reduces NRG's ability to pay dividends or fund its operations, capital expenditures and future business opportunities;

•limiting NRG's ability to enter into long-term power sales or fuel purchases, which require credit support;

•adversely impacting NRG's credit rating, which could increase borrowing costs;

•limiting NRG's ability to obtain additional financing for working capital, including collateral postings, capital expenditures, debt service requirements, acquisitions and general corporate purposes;

•limiting NRG's ability to adjust to changing market conditions and placing it at a competitive disadvantage compared to its competitors, who may have less debt; and

•exposing NRG to the risk of increased interest rates because certain of its borrowings are at variable rates of interest.

The Company’s debt agreements contain financial and other restrictive covenants that may limit the Company's ability to return capital to stockholders, including by paying dividends, or otherwise engage in activities that may be in its long-term best interests. NRG's failure to comply with those covenants could result in an event of default which, if not cured or waived, could result in the acceleration of such indebtedness, which in turn could cause a cross default to NRG's other indebtedness. NRG's assets and available cash balances may not be sufficient to fully repay all outstanding indebtedness if accelerated upon an event of default. If NRG is unable to repay, refinance, or restructure its indebtedness as required, or amend the covenants contained in those agreements, the lenders or other creditors may be entitled to obtain a lien or institute foreclosure proceedings against its assets, which could have a material adverse effect on its business, results of operations and financial condition. In addition, the Company's Revolving Credit Facility and sustainability-linked bonds include a sustainability-linked metric, which could result in increased interest expense for the Company if the sustainability metrics set forth therein are not achieved. Furthermore, financial and other restrictive covenants contained in any subsidiary or project level debt may limit the ability of NRG to receive distributions from such subsidiary.

In addition, NRG's ability to arrange financing, either at the corporate level, a non-recourse project-level subsidiary or otherwise, and the costs of such capital are dependent on numerous factors, including: general economic and capital market conditions, credit availability from banks and other financial institutions, investor confidence in NRG, its partners and the regional wholesale power markets, NRG's financial performance and the financial performance of its subsidiaries, NRG's level of indebtedness and compliance with covenants in debt agreements, maintenance of acceptable credit ratings, cash flow and provisions of tax and securities laws that may impact raising capital.

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NRG's ability to meet its payment obligations under its debt agreements is dependent on its ability to generate significant cash flows or obtain additional capital in the future. This, to some extent, is subject to market, economic, financial, competitive, legislative, and regulatory factors as well as other factors that are beyond its control. NRG may not be successful in obtaining additional capital for these or other reasons. The failure to obtain additional capital on terms acceptable to NRG, or at all, from time to time may have a material adverse effect on its business and operations.

NRG's preferred stock is senior to its common stock, and a failure to pay dividends on its preferred stock will prohibit the payment of dividends on its common stock.

NRG has outstanding 650,000 shares of 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, with a $1,000 liquidation preference per share. The Series A Preferred Stock is senior to NRG's common stock in right of payment of dividends and other distributions and could adversely affect NRG's ability to declare or pay dividends or distributions on its common stock. In the event of NRG's voluntary or involuntary liquidation, winding-up or dissolution, the holders of Series A Preferred Stock must receive their $1,000 per share, plus accumulated but unpaid dividends, prior to any distributions to holder of common stock. NRG must be current on dividends payable to holders of Series A Preferred Stock before any dividends can be paid on its common stock.

Whenever dividends on any shares of Series A Preferred Stock have not been declared and paid for the equivalent of three or more dividend payments, whether or not for consecutive dividend periods, the number of directors on the Company's Board of Directors will be increased by two, and the holders of Series A Preferred Stock will have the right to elect two members of the Company's Board of Directors to fill such newly created openings.

Adverse economic conditions could adversely affect NRG’s business, financial condition, results of operations and cash flows.

Adverse economic conditions, including inflation, and declines in wholesale energy prices, partially resulting from adverse economic conditions, may impact NRG's results of operations, including by reducing the demand for energy commodities. In general, economic and commodity market conditions will continue to impact NRG’s unhedged future energy margins, liquidity, earnings growth and overall financial condition. Macroeconomic factors may also impact consumer spending, which could adversely affect the Company’s Smart Home services, and increase the Company’s costs for such products and services, which it may not be able to pass on to customers. In addition, adverse economic conditions, declines in wholesale energy prices, reduced demand for energy and other factors may negatively impact the trading price of NRG’s common stock and impact forecasted cash flows, which may require NRG to evaluate its goodwill and other long-lived assets for impairment. Any such impairment could have a material impact on NRG’s financial condition.

Goodwill and other intangible assets that NRG has recorded in connection with its acquisitions are subject to impairment evaluations and, as a result, the Company could be required to write off some or all of this goodwill and other intangible assets, which may adversely affect the Company's financial condition and results of operations.

Goodwill is not amortized but is reviewed annually or more frequently for impairment. Other intangibles are also reviewed at least annually or more frequently, if certain conditions exist, and are amortized. Any reduction in or impairment of the value of goodwill or other intangible assets will result in a charge against earnings, which could materially adversely affect NRG's reported results of operations and financial position in future periods.

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Annual Report on Form 10-K of NRG Energy, Inc., or NRG or the Company, includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, or Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended, or Exchange Act. The words "believes," "projects," "anticipates," "plans," "expects," "intends," "estimates," "should," "forecasts," 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 NRG's actual results, performance and achievements, or industry results, to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. These factors, risks and uncertainties include the factors described under Item 1A — Risk Factors and the following:

•Business uncertainties related to NRG's ability to integrate the operations of Vivint Smart Home with its own;

•NRG's ability to obtain and maintain retail market share;

•General economic conditions, changes in the wholesale power and gas markets and fluctuations in the cost of fuel;

•Volatile power and gas supply costs and demand for power and gas, including the impacts of weather;

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

•The effectiveness of NRG's risk management policies and procedures and the ability of NRG's counterparties to satisfy their financial commitments;

•NRG's ability to enter into contracts to sell power or gas and procure fuel on acceptable terms and prices;

•NRG's ability to successfully integrate, realize cost savings and manage any acquired businesses;

•NRG's ability to engage in successful acquisitions and divestitures, as well as other mergers and acquisitions activity;

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

•Counterparties' collateral demands and other factors affecting NRG's liquidity position and financial condition;

•NRG's ability to operate its businesses efficiently and generate earnings and cash flows from its asset-based businesses in relation to its debt and other obligations;

•The liquidity and competitiveness of wholesale markets for energy commodities;

•Changes in law, including judicial and regulatory decisions;

•Government regulation, including changes in market rules, rates, tariffs and environmental laws;

•NRG's ability to develop and innovate new products, as retail and wholesale markets continue to change and evolve;

•Price mitigation strategies and other market structures employed by ISOs or RTOs that result in a failure to adequately and fairly compensate NRG's generation units;

•NRG's ability to mitigate forced outage risk;

•NRG's ability to borrow funds and access capital markets, as well as NRG's substantial indebtedness and the possibility that NRG may incur additional indebtedness in the future;

•Operating and financial restrictions placed on NRG and its subsidiaries that are contained in NRG's corporate credit agreements, and in debt and other agreements of certain of NRG subsidiaries and project affiliates generally;

•The ability of NRG and its counterparties to develop and build new power generation facilities;

•NRG's ability to implement its strategy of finding ways to meet the challenges of climate change, clean air and protecting natural resources, while taking advantage of business opportunities;

•NRG's ability to increase cash from operations through operational and market initiatives, corporate efficiencies, asset strategy, and a range of other programs throughout NRG to reduce costs or generate revenues;

•NRG's ability to successfully evaluate investments and achieve intended financial results in new business and growth initiatives; and

•NRG's ability to develop and maintain successful partnering relationships as needed.

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In addition, unlisted factors may present significant additional obstacles to the realization of forward-looking statements. Forward-looking statements speak only as of the date they were made and NRG undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise except as otherwise required by applicable laws. The foregoing factors that could cause NRG's actual results to differ materially from those contemplated in any forward-looking statements included in this Annual Report on Form 10-K should not be construed as exhaustive.

Item 1B — Unresolved Staff Comments

None.

Item 1C — Cybersecurity

Risk Management and Strategy

The Company leverages a comprehensive, multi-tiered cybersecurity strategy to manage cybersecurity risk based on criteria established by the NIST Cybersecurity Framework. As part of the cybersecurity strategy the Company utilizes a range of industry and regulatory standards including, but not limited to, NERC-CIP, PCI DSS, and IoT Security Assurance Framework. Compliance with NERC-CIP standards is mandated for entities involved in power generation, transmission, and distribution by regulatory bodies to which the purpose of is to protect critical infrastructure within the United States. NRG engages certified external assessors to ensure compliance with standards.

The Company’s strategy seeks to align underlying processes not only with industry standards but also mirror best practices among peer organizations. The strategy ensures a standardized method across all activities at NRG allowing for consistent recognition, assessment and potential mitigation of significant cybersecurity risks. To further the strategy, the Company established the NRG Cybersecurity Integration Center ("CIC") which is composed of experienced team members from across cybersecurity disciplines with relevant educational and industry experience. The CIC provides the following functions to the Company: cyber governance, operations, detection and response, engineering, testing, cyber risk management (including third-party), compliance, training and awareness, and reporting. The CIC utilizes advanced continuous monitoring systems and investigative techniques for real-time threat detection. The systematic monitoring approach allows for risk classification and prioritization based on potential impacts, facilitating targeted resource allocation according to risk severity. The Company conducts regular penetration testing to proactively identify vulnerabilities and enhance its defense measures. The Company engages third-party assessors to gain comprehensive insights into its cyber risk profile's composition.

The Company relies on third-party service providers in the normal course of business. The Company has established a comprehensive approach to identify and manage cybersecurity risks associated with providers including, but not limited to, rigorous due diligence and assessments of third-party service providers' cybersecurity protocols before engagement, requirements relating to information handling, incident notification and assessment against the Company's cybersecurity requirements. Furthermore, the Company has implemented additional control measures and procedures in business processes to enable continuous risk identification, assessment and to support monitoring mechanisms to oversee and manage supplier cybersecurity practices.

Through December 31, 2023, no cybersecurity threats have been identified or are anticipated to have a material adverse effect on NRG’s business strategy, financial standing, or operational performance.

Governance

Management

The Chief Information Security Officer ("CISO") is the head of cybersecurity for the Company and leads the NRG Cybersecurity Integration Center. The CISO has decades of professional experience, education, and certification in security analysis, design, implementation, and management, with a particularly strong background in technical vulnerability assessment and program development. Within various roles throughout the CISO's career, he has overseen information assurance and cybersecurity efforts, including critical infrastructure protection in government agencies and industry.

At least twice per year, the CISO provides comprehensive updates to the Board on cybersecurity and any recent developments impacting the Company. These updates include, among other items:

•Incident reports and developments from any cybersecurity events;

•Current cybersecurity landscape and emerging cybersecurity threats, with a particular emphasis on Company and industry-specific threats; and

•Status of ongoing initiatives to strengthen the Company's cybersecurity program.

In addition, the CISO regularly informs other members of senior management, including the Interim President and CEO, of all aspects related to cybersecurity risks and incidents. This is intended to ensure that the highest levels of management remain

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updated on the cybersecurity preparedness and potential risks facing the Company. Furthermore, significant cybersecurity matters and strategic risk management decisions are escalated to the Board of Directors ensuring that they have comprehensive oversight and can provide guidance on critical cybersecurity issues.

In preparation for a potential cybersecurity incident, the Company has implemented structured processes and procedures aligned with the NIST framework. This framework provides a foundation for a systematic and consistent approach to preparing for, identifying, containing, eradicating, and recovering from incidents. The effectiveness of these protocols is routinely verified through tabletop exercises involving relevant teams and Company leadership. In accordance with the Company’s process and procedures, incidents which may have a material impact on the Company are promptly referred to senior leadership and the Board of Directors for review and appropriate determination.

Board of Directors

The Board of Directors is primarily responsible for the risk oversight of the Company, and has delegated oversight of risks related to cybersecurity to the Finance and Risk Management ("FARM") Committee of the Board. The FARM Committee regularly reports on its activities to the Board after each meeting. The FARM Committee, as well as the overall Board, is composed of members with diverse expertise, including risk management, incident response and technology. The Board is aware of the critical nature of managing risks associated with cybersecurity threats and has worked with the Company’s management to establish comprehensive oversight mechanisms to ensure effective cybersecurity governance.

The FARM Committee and the Board receive updates on any significant developments in the cybersecurity domain, seeking to ensure that the Board’s oversight is proactive and responsive. The Board remains involved in ensuring that cybersecurity considerations are integrated into the Company’s broader strategic objectives. Pursuant to the charter of the FARM Committee, the Committee's responsibilities include an annual review of the Company’s cybersecurity program and the effectiveness of its risk management strategies. This review is intended to help identify areas for improvement and ensure the alignment of cybersecurity efforts with the overall risk management framework.

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Item 2 — Properties

Listed below are descriptions of NRG's interests in facilities, operations and/or projects owned or leased as of December 31, 2023. The rated MW capacity figures provided represent nominal summer MW capacity of power generated. Net MW capacity is adjusted for the Company's owned or leased interest as of December 31, 2023. The Company believes its existing facilities, operations and/or projects are suitable for the conduct of its business. The following table summarizes NRG's power production and cogeneration facilities by region:

Name of Facility	Power Market	Plant Type	Primary Fuel	Location	Rated MW Capacity(a)	Net MW Capacity(b)	% Owned
Texas
Cedar Bayou	ERCOT	Fossil	Natural Gas	TX	1,494	1,494	100.0
Cedar Bayou 4	ERCOT	Fossil	Natural Gas	TX	504	252	50.0
Elbow Creek	ERCOT	Other	Battery Storage	TX	2	2	100.0
Greens Bayou	ERCOT	Fossil	Natural Gas	TX	327	327	100.0
Limestone	ERCOT	Fossil	Coal	TX	1,660	1,660	100.0
San Jacinto	ERCOT	Fossil	Natural Gas	TX	160	160	100.0
T.H. Wharton	ERCOT	Fossil	Natural Gas	TX	1,002	1,002	100.0
W.A. Parish(c)	ERCOT	Fossil	Coal	TX	2,514	2,514	100.0
W.A. Parish	ERCOT	Fossil	Natural Gas	TX	1,118	1,118	100.0
Total Texas					8,781	8,529
East
Chalk Point	PJM	Fossil	Natural Gas	MD	80	80	100.0
Fisk	PJM	Fossil	Oil	IL	171	171	100.0
Indian River(d)	PJM	Fossil	Coal	DE	410	410	100.0
Indian River	PJM	Fossil	Oil	DE	16	16	100.0
Powerton(e)	PJM	Fossil	Coal	IL	1,538	1,538	100.0
Vienna(f)	PJM	Fossil	Oil	MD	167	167	100.0
Waukegan	PJM	Fossil	Oil	IL	101	101	100.0
Total East					2,483	2,483
West/Services/Other
Cottonwood	MISO	Fossil	Natural Gas	TX	1,166	1,166	___(g)
Gladstone		Fossil	Coal	AUS	1,613	605	37.5
Ivanpah	CAISO	Renewable	Solar	CA	391	213	54.5
Midway-Sunset	CAISO	Fossil	Natural Gas	CA	226	113	50.0
Stadiums and Other		Renewable	Solar	various	3	3	100.0
Total West/Services/Other					3,399	2,100
Total Fleet					14,663	13,112

(a)MW capacity of the facility without taking into account NRG ownership percentage

(b)Actual capacity can vary depending on factors including weather conditions, operational conditions, and other factors. Additionally, ERCOT and PJM require periodic demonstration of capability, and the capacity may vary individually and in the aggregate from time to time

(c)In May 2022, W.A. Parish Unit 8 came offline as a result of damage to the steam turbine/generator. The extended forced outage ended in September 2023 and the unit has returned to service

(d)The Company previously announced the shut down of the Indian River facility. However, PJM identified reliability impacts resulting from the proposed deactivation and Indian River Unit 4 currently remains active under a RMR agreement that ends December 31, 2026

(e)Powerton is projected to close by December 31, 2028 to comply with ELG regulations

(f)A retirement notice was filed with PJM that the Vienna facility will retire in June 2025

(g)NRG leases 100% interests in the Cottonwood facility through a facility lease agreement expiring in May 2025 and operates the Cottonwood facility

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The following table summarizes the primary changes that occurred during 2023:

Name of Facility	Power Market	Plant Type	Primary Fuel	Status	Location	Rated MW Capacity	Net MW Capacity	% Owned
Texas
Gregory	ERCOT	Fossil	Natural Gas	Sold	TX	365	365	100.0	%
South Texas Project	ERCOT	Nuclear	Uranium	Sold	TX	2,572	1,132	44.0	%
East
Astoria Turbines	NYISO	Fossil	Natural Gas	Retired	NY	420	420	100.0	%
Joliet	PJM	Fossil	Natural Gas	Retired	IL	1,381	1,381	100.0	%
					Total	4,738	3,298

Other Properties

NRG owns several real properties and facilities related to its generation assets, other vacant real property unrelated to its generation assets, and properties not used for operational purposes. NRG believes it has satisfactory title to its plants and facilities in accordance with standards generally accepted in the electric power industry, subject to exceptions that, in the Company's opinion, would not have a material adverse effect on the use or value of its portfolio.

NRG leases its operational and corporate headquarters in Houston, Texas, its financial and commercial corporate offices in Princeton, New Jersey, its smart home corporate offices in Provo, Utah, as well as its retail operations offices, smart home monitoring stations, call centers, warehouses and various other office space.

Item 3 — Legal Proceedings

See Item 15 — Note 23, Commitments and Contingencies, to the Consolidated Financial Statements for discussion of the material legal proceedings to which NRG is a party.

Item 4 — Mine Safety Disclosures

There have been no events that are required to be reported under this Item.

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PART II

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

Market Information and Holders

NRG's common stock trades on the New York Stock Exchange under the symbol "NRG". NRG's authorized capital stock consists of 500,000,000 shares of common stock and 10,000,000 shares of preferred stock. A total of 25,000,000 shares of the Company's common stock are authorized for issuance under the NRG LTIP, and a total of 17,500,000 shares of common stock are authorized for issuance under the Vivint LTIP. For more information about the LTIPs, refer to Item 12 — Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters and Item 15 — Note 21, Stock-Based Compensation, to the Consolidated Financial Statements.

As of February 1, 2024, there were 15,102 common stockholders of record.

On June 22, 2023, the Company updated its capital allocation framework, and plans, after debt reduction, to return approximately 80% of excess cash to shareholders and invest 20% in growth initiatives. The Company expects to return the capital to shareholders through share repurchases and dividends on its common stock.

Consistent with its capital allocation framework, in 2021, 2022 and 2023, the Company increased the annual dividend on its common stock to $1.30, $1.40 and $1.51 per share, respectively, representing an 8% increase each year. The Company further increased the annual dividend by 8% to $1.63 per share beginning in the first quarter of 2024. The long-term capital allocation policy targets an annual dividend growth rate of 7-9% per share.

Issuer Purchases of Equity Securities

NRG engages in share repurchase programs with the goal of returning excess cash to shareholders. The share repurchase plan permits the execution of the plan through open-market purchases, private transactions, accelerated share repurchases and other similar transactions. The timing, price and volume of repurchases is based on a number of factors, including available capital, market conditions, and compliance with associated laws and regulations.

On June 22, 2023, as part of the updated capital allocation framework, the Company announced that the Board of Directors has increased the share repurchase authorization of its common stock to $2.7 billion to be executed through 2025. Through December 31, 2023, the Company completed $1.2 billion of share repurchases under the $2.7 billion authorization. For further information regarding share repurchases, see Item 15 — Note 16, Capital Structure in this Form 10-K.

The table below sets forth the information with respect to purchases made by or on behalf of NRG or any "affiliated purchaser" (as defined in Rule 10b-18(a)(3) under the Exchange Act) of NRG's common stock during the quarter ended December 31, 2023.

For the three months ended December 31, 2023	Total Number of Shares Purchased	Average Price Paid per Share(a)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (in millions)(b)
Month #1
(October 1, 2023 to October 31, 2023	3,732,657	$	40.17	3,732,657	$	2,500
Month #2
(November 1, 2023 to November 30, 2023)	4,494,224	(c)		4,494,224	$	1,550
Month #3
(December 1, 2023 to December 31, 2023)	13,181,918	(c)		13,181,918	$	1,550
Total at December 31, 2023	21,408,799			21,408,799

(a)The average price paid per share excludes excise taxes and commissions per share paid in connection with the open market share repurchases

(b)Includes commissions of $0.015 per share paid in connection with the open market share repurchases

(c)Represents shares delivered under the November 6, 2023 ASR agreements. The total number of shares delivered and the average price per share under the ASR agreements will be determined at the end of the ASR period which is expected to occur in March of 2024. See Item 15—Note 16, Capital Structure for additional information on the ASR agreements

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Director and Officer Trading Arrangements

The Company’s officers and directors are required to comply with the Company’s Securities Trading and Non-Disclosure Policy at all times, including during a share repurchase program. The securities trading and non-disclosure policy, among other things, prohibits trading in the Company’s securities when in possession of material non-public information and restricts the ability of certain officers or directors from transacting in the Company’s securities during specific blackout periods, subject to certain limited exceptions, including transactions pursuant to a Rule 10b5-1 trading plan that complies with the conditions of Securities Exchange Act Rule 10b5-1. The Company’s policy also requires officers and directors to obtain preclearance in advance of effecting any purchase, sale or other trading of Company stock. See Item 9B — Other Information, for details of any "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement" by any director or officer of the Company during the three months ended December 31, 2023.

Stock Performance Graph

The performance graph below compares the cumulative total stockholder return on NRG's common stock for the period December 31, 2018 through December 31, 2023, with the cumulative total return of the Standard & Poor's 500 Composite Stock Price Index ("S&P 500") and the Philadelphia Utility Sector Index ("UTY").

The performance graph shown below is being furnished and compares each period assuming that $100 was invested on December 31, 2018, in each of the common stock of NRG, the stocks included in the S&P 500 and the stocks included in the UTY, and that all dividends were reinvested.

Comparison of Cumulative Total Return

	12/31/2018		12/31/2019		12/31/2020		12/31/2021		12/31/2022		12/31/2023
NRG Energy, Inc.	$	100.00	$	100.69	$	98.53	$	116.81	$	89.40	$	151.29
S&P 500	100.00		131.49		155.68		200.37		164.08		207.21
UTY	100.00		126.82		130.27		154.04		155.04		140.83

Item 6 — Reserved

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Item 7 — Management's Discussion and Analysis of Financial Condition and Results of Operations

The discussion and analysis below has been organized as follows:

•Executive Summary, including the business environment in which the Company operates, a discussion of regulation, weather, competition and other factors that affect the business, and other significant events that are important to understanding the results of operations and financial condition;

•Results of operations for the years ended December 31, 2023 and December 31, 2022, including an explanation of significant differences between the periods in the specific line items of NRG's Consolidated Statements of Operations;

•Liquidity and capital resources including liquidity position, financial condition addressing credit ratings, material cash requirements and commitments, and other obligations; and

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

As you read this discussion and analysis, refer to NRG's Consolidated Statements of Operations in this Form 10-K, which present the results of the Company's operations for the years ended December 31, 2023 and 2022, and also refer to Item 1 — Business to this Form 10-K for more detail discussion about the Company's business. A discussion and analysis of fiscal year 2021 may be found in Part II, Item 7 — Management's Discussion and Analysis of Financial Condition and Results of Operations of the Annual Report on Form 10-K for the fiscal year ended December 31, 2022.

Executive Summary

NRG Energy, Inc., or NRG or the Company, sits at the intersection of energy and home services. NRG is a leading energy and home services company fueled by market-leading brands, proprietary technologies and complementary sales channels. Across the U.S. and Canada, NRG delivers innovative, sustainable solutions, predominately under the brand names such as NRG, Reliant, Direct Energy, Green Mountain Energy, and Vivint, while also advocating for competitive energy markets and customer choice. The Company has a customer base that includes approximately 8 million residential consumers in addition to commercial, industrial, and wholesale customers, supported by approximately 13 GW of generation as of December 31, 2023.

Business Environment

The industry dynamics and external influences affecting the Company, its businesses, and the retail energy and power generation industry in 2023 and for the future medium term include:

Market Dynamics — The price of natural gas plays an important role in setting the price of electricity in many of the regions where NRG operates. Natural gas prices are driven by variables including demand from the industrial, residential, and electric sectors, productivity across natural gas supply basins, costs of natural gas production, changes in pipeline infrastructure, global LNG demand, exports of natural gas, and the financial and hedging profile of natural gas customers and producers. In 2023, the average natural gas price at Henry Hub was $2.74 per MMBtu compared to $6.64 per MMBtu in 2022, representing a decrease of 59%.

NRG may experience impacts to gross margins due to significant, rapid changes in current natural gas prices, the impact those prices have on power prices, and the lag in its ability to make a corresponding adjustment to the retail rates it charges customers on term and month to month contracts. The Company hedges its load commitments in order to mitigate the impact of changes in commodity prices, and as a result, these gross margin impacts would be realized in future periods until it is able to make the corresponding adjustments to the retail customer rates.

The relative price of natural gas as compared to coal and prevailing power prices are the primary driver of coal demand. Coal commodity prices decreased slightly in 2023.

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Electricity Prices — The price of electricity is a key determinant of the profitability of the Company. Many variables such as the price of different fuels, weather, load growth and unit availability all coalesce to impact the final price for electricity and the Company's profitability. An increase in supply cost volatility in the competitive retail markets may result in smaller companies choosing to exit the market, which may result in further consolidation in the competitive retail space. The following table summarizes average on-peak power prices for each of the major markets in which NRG operates. For the year ended December 31, 2023, as compared to the same period in 2022, Texas, East and West average on-peak power prices decreased as a result of lower natural gas prices.

	Average On-Peak Power Price ($/MWh)
	Year Ended December 31,				2023 vs 2022
Region	2023		2022		Change %
Texas
ERCOT - Houston(a)	$	74.32	$	90.62	(18)	%
ERCOT - North(a)	72.89		78.34		(7)	%
East
NY J/NYC(b)	38.95		93.58		(58)	%
NEPOOL(b)	41.36		92.42		(55)	%
COMED (PJM)(b)	32.72		71.86		(54)	%
PJM West Hub(b)	39.34		83.48		(53)	%
West
CAISO - SP15(b)	60.17		87.67		(31)	%
MISO - Louisiana Hub(b)	33.64		71.12		(53)	%

(a)Average on-peak power prices based on real time settlement prices as published by the respective ISOs

(b)Average on-peak power prices based on day-ahead settlement prices as published by the respective ISOs

Increased Awareness of, and Action to Combat, Climate Change —Diverse groups of stakeholders, including investors, asset managers, financial institutions, non-government organizations, industry coalitions, individual companies, consumer groups and academic institutions, are increasingly engaged in efforts to limit global warming in the post-industrial era to 1.5 degrees Celsius. As a result, policymakers and regulators at regional, national, sub-national and local levels of government, both in the U.S. and other parts of the world, are increasingly focused on actions to combat climate change.

NRG actively monitors climate change related developments that could impact its business and regularly engages with a diverse set of stakeholders on these issues. Such engagement helps the Company identify and pursue potential opportunities both to decarbonize its business and better serve its customers. NRG is committed to providing transparent disclosures of its climate risks and opportunities to stakeholders. The Company was an early supporter of the Task Force on Climate-related Financial Disclosures ("TCFD") recommendations after they were issued in 2017, published a TCFD mapping disclosure in December 2020 and issued a stand-alone TCFD report in December 2021.

Lower Carbon Infrastructure Development — Policy mechanisms at the state and federal level, including production and investment tax credits, cash grants, loan guarantees, accelerated depreciation tax benefits, RPS, and carbon trading plans, have supported and continue to support the development of renewable generation, demand-side and smart grid, and other lower carbon infrastructure technologies. The U.S. Inflation Reduction Act, signed into law in August 2022, is intended to further support the deployment of lower carbon energy technologies. As costs associated with the development of lower carbon infrastructure, such as wind and solar generating facilities, continue to evolve and impact the development of lower carbon infrastructure in the markets where the Company participates, it may impact the ability of the Company's generating facilities to participate in those markets. According to ERCOT, 41% of 2023 energy consumption in the ERCOT market was generated from carbon emission-free resources, with wind power contributing 24%. In addition, as subsidies and incentives contribute to increases in renewable power sources, customer awareness and preferences are shifting toward sustainable solutions. Increased demand for sustainable energy products from both residential and commercial customers creates opportunities for diversified product offerings in competitive retail markets.

Digitization and Customization — The electric industry is experiencing major technological changes in the way power is distributed and consumed by end-use customers. The electric grid is shifting from a centralized analog system, where power is generated from limited sources and flows in one direction, to a decentralized multidirectional system, where power can be generated from a number of distributed resources and stored or dispatched on an as-needed basis. In addition, customers are seeking new ways to engage with their power providers. Technologies like smart thermostats, smart appliances and electric vehicles are giving individuals more choice and control over their electricity usage. Power providers are starting to engage with customers who have transitioned to smart homes with new offerings, including but not limited to behind-the-meter demand

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response, or virtual power plant products. Companies with large customer bases in competitive market places are poised to create further engagement with their customer bases and help their customers further integrate their smart home into their daily lives.

Weather — Weather conditions in the regions of the U.S. in which NRG conducts business influence the Company's financial results. Weather conditions can affect the supply and demand for electricity and fuels and may also impact the availability of the Company's generating assets. Changes in energy supply and demand may impact the price of these energy commodities in both the spot and forward markets, which may affect the Company's results in any given period. Typically, demand for and the price of electricity is higher in the summer and the winter seasons, when temperatures and resultant demand are more extreme. The demand for and price of natural gas is also generally higher in the winter. However, all regions of the U.S. typically do not experience extreme weather conditions at the same time, thus NRG's operations are typically not exposed to the effects of extreme weather in all parts of its business at once.

Other Factors — A number of other factors significantly influence the level and volatility of prices for energy commodities and related derivative products for NRG's business. These factors include:

•seasonal, daily and hourly changes in demand;

•extreme peak demands;

•performance of renewable generation;

•available supply resources;

•transportation and transmission availability and reliability within and between regions;

•location of NRG's generating facilities relative to the location of its load-serving opportunities;

•procedures used to maintain the integrity of the physical electricity system during extreme conditions; and

•changes in the nature and extent of federal and state regulations.

These factors can affect energy commodity and derivative prices in different ways and to different degrees. These effects may vary throughout the country as a result of regional differences in:

•weather conditions;

•market liquidity;

•capability and reliability of the physical electricity and gas systems;

•local transportation systems; and

•the nature and extent of electricity deregulation.

Environmental Matters, Regulatory Matters and Legal Proceedings — Details of environmental matters are presented in Item 15 — Note 25, Environmental Matters, to the Consolidated Financial Statements and Item 1 — Business, Environmental Matters. Details of regulatory matters are presented in Item 15 — Note 24, Regulatory Matters, to the Consolidated Financial Statements and Item 1 — Business, Regulatory Matters. Details of legal proceedings are presented in Item 15 — Note 23, Commitments and Contingencies, to the Consolidated Financial Statements. Some of this information relates to costs that may be material to the Company's financial results.

Significant Events

The following significant events occurred during 2023 and through the filing date, as further described within this Management's Discussion and Analysis and the Consolidated Financial Statements:

Vivint Smart Home Acquisition and related financings

On March 10, 2023, the Company completed the acquisition of Vivint Smart Home. The Company paid $12 per share, or $2.6 billion in cash. See Item 15 — Note 4, Acquisitions and Dispositions, to the Consolidated Financial Statements for further discussion.

On March 9, 2023, the Company issued 650,000 shares of 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock. The proceeds, net of issuance costs, of $635 million were used to partially fund the Vivint Smart Home acquisition.

On March 9, 2023, the Company issued $740 million of aggregate principal amount of 7.000% senior secured first lien notes due 2033. The net proceeds of $724 million, net of issuance costs, were used to partially fund the Vivint Smart Home acquisition.

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Dispositions

On November 1, 2023, the Company closed on the previously announced sale of its 44% equity interest in STP to Constellation. Proceeds of $1.75 billion were reduced by working capital and other adjustments of $96 million, resulting in net proceeds of $1.654 billion.

On October 2, 2023, the Company closed on the sale of its 100% ownership in the Gregory natural gas generating facility in Texas for $102 million.

On January 6, 2023, NRG closed on the sale of land and related assets from the Astoria site, within the East region of operations, for proceeds of $212 million subject to transaction fees of $3 million and certain indemnifications. NRG recognized a gain on the sale of $199 million. As part of the transaction, NRG entered into an agreement to lease the land back for the purpose of operating the Astoria gas turbines. Decommissioning was completed in December 2023 and the lease agreement has been terminated.

Operations

In May 2022, W.A. Parish Unit 8 came offline as a result of damage to the steam turbine/generator. The extended forced outage ended in September 2023 and the unit has returned to service.

During the second quarter of 2022, the Company announced the planned retirement of the Joliet generating facility in 2023. On September 1, 2023, the Joliet generating facility fully retired.

The Company's strategy is to procure mid to long-term renewable generation through power purchase agreements. As of December 31, 2023, NRG has entered into Renewable PPAs totaling approximately 1.9 GW with third-party project developers and other counterparties, of which approximately 1.1 GW are operational. The average tenor of these agreements is eleven years. The Company expects to continue evaluating and executing similar agreements that support the needs of the business. The total GW entered into through Renewable PPAs may be impacted by contract terminations when they occur.

Capital Allocation

In June 2023, NRG revised its long-term capital allocation policy to target allocating approximately 80% of cash available for allocation after debt reduction to be returned to shareholders. As part of the revised capital allocation framework, the Company announced an increase to its share repurchase authorization to $2.7 billion, to be executed through 2025.

On November 6, 2023, the Company executed Accelerated Share Repurchase agreements to repurchase a total of $950 million of NRG's outstanding common stock. Under the ASR, the Company paid a total of $950 million and will receive shares of NRG's common stock on specified settlement dates.

During the year ended December 31, 2023, the Company completed $1.2 billion of share repurchases, including the $950 million ASR and $200 million of open market repurchases, under the $2.7 billion authorization. See Item 15 - Note 16, Capital Structure, to the Consolidated Financial Statements for additional discussion.

In the first quarter of 2023, NRG increased the annual dividend on its common stock to $1.51 from $1.40 per share, representing an 8% increase from 2022. Beginning in the first quarter of 2024, NRG increased the annual dividend by 8% to $1.63 per share. The Company expects to target an annual dividend growth rate of 7-9% per share in subsequent years.

During 2023, the Company reduced its debt by $900 million using funds from cash from operations. Additionally, the Company redeemed $620 million in aggregate principal amount of its 3.875% Senior Notes, due 2032, for $502 million using a portion of the proceeds from the sale of STP.

The Company intends to spend approximately $500 million reducing debt during 2024 to maintain its targeted credit metrics. The Company intends to fund the debt reduction from cash from operations.

47

Consolidated Results of Operations for the years ended December 31, 2023 and 2022

The following table provides selected financial information for the Company:

	Year Ended December 31,
(In millions)	2023		2022		Change
Revenue
Retail revenue	$	27,467	$	29,722	$	(2,255)
Energy revenue(a)	553		1,250		(697)
Capacity revenue(a)	197		272		(75)
Mark-to-market for economic hedging activities	144		(83)		227
Contract amortization	(32)		(39)		7
Other revenues(a)(b)	494		421		73
Total revenue	28,823		31,543		(2,720)
Operating Costs and Expenses
Cost of fuel	992		1,919		927
Purchased energy and other cost of sales(c)	20,647		24,984		4,337
Mark-to-market for economic hedging activities	3,007		(1,331)		(4,338)
Contract and emissions credit amortization(c)	93		111		18
Operations and maintenance	1,397		1,352		(45)
Other cost of operations	390		411		21
Cost of operations (excluding depreciation and amortization shown below)	26,526		27,446		920
Depreciation and amortization	1,127		634		(493)
Impairment losses	26		206		180
Selling, general and administrative costs	1,968		1,228		(740)
Provision for credit losses	251		11		(240)
Acquisition-related transaction and integration costs	119		52		(67)
Total operating costs and expenses	30,017		29,577		(440)
Gain on sale of assets	1,578		52		1,526
Operating Income	384		2,018		(1,634)
Other Income/(Expense)
Equity in earnings of unconsolidated affiliates	16		6		10
Impairment losses on investments	(102)		—		(102)
Other income, net	47		56		(9)
Gain on debt extinguishment	109		—		109
Interest expense	(667)		(417)		(250)
Total other expenses	(597)		(355)		(242)
(Loss)/Income Before Income Taxes	(213)		1,663		(1,876)
Income tax (benefit)/expense	(11)		442		(453)
Net (Loss)/Income	$	(202)	$	1,221	$	(1,423)

(a)Includes realized gains and losses from financially settled transactions

(b)Includes trading gains and losses and ancillary revenues

(c)Includes amortization of SO2 and NOx credits and excludes amortization of RGGI credits

Gross Margin

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

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

48

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 the sum of retail revenue, energy revenue, capacity revenue and other revenue, less cost of fuels, purchased energy and other cost of sales. Economic gross margin does not include mark-to-market gains or losses on economic hedging activities, contract amortization, emission credit amortization, depreciation and amortization, operations and maintenance, or other costs of operations.

The following tables present the composition and reconciliation of gross margin and economic gross margin for the years ended December 31, 2023 and 2022:

	Year Ended December 31, 2023
($ in millions, except otherwise noted)	Texas		East		West/Services/Other		Vivint Smart Home		Corporate/Eliminations		Total
Retail revenue	$	10,030	$	11,946	$	3,943	$	1,549	$	(1)	$	27,467
Energy revenue	77		291		185		—		—		553
Capacity revenue	—		197		2		—		(2)		197
Mark-to-market for economic hedging activities	—		57		103		—		(16)		144
Contract amortization	—		(32)		—		—		—		(32)
Other revenue(a)	369		88		48		—		(11)		494
Total revenue	10,476		12,547		4,281		1,549		(30)		28,823
Cost of fuel	(760)		(112)		(120)		—		—		(992)
Purchased energy and other costs of sales(b)(c)(d)	(6,288)		(10,683)		(3,532)		(153)		9		(20,647)
Mark-to-market for economic hedging activities	315		(2,471)		(867)		—		16		(3,007)
Contract and emissions credit amortization	(11)		(68)		(14)		—		—		(93)
Depreciation and amortization	(294)		(116)		(95)		(586)		(36)		(1,127)
Gross margin	$	3,438	$	(903)	$	(347)	$	810	$	(41)	$	2,957
Less: Mark-to-market for economic hedging activities, net	315		(2,414)		(764)		—		—		(2,863)
Less: Contract and emissions credit amortization, net	(11)		(100)		(14)		—		—		(125)
Less: Depreciation and amortization	(294)		(116)		(95)		(586)		(36)		(1,127)
Economic gross margin	$	3,428	$	1,727	$	526	$	1,396	$	(5)	$	7,072
(a)Includes trading gains and losses and ancillary revenues
(b)Includes capacity and emissions credits
(c)Includes $3.1 billion, $244 million and $1.1 billion of TDSP expense in Texas, East, and West/Services/Other respectively
(d)Excludes depreciation and amortization shown separately

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	Year Ended December 31, 2023
Business Metrics	Texas	East	West/Services/Other	Vivint Smart Home	Corporate/Eliminations	Total
Home electricity sales volume (GWh)	40,032	12,838	2,243	—	—	55,113
Business electricity sales volume (GWh)	40,250	46,438	10,393	—	—	97,081
Home natural gas retail sales volumes (MDth)	—	49,990	75,150	—	—	125,140
Business natural gas retail sales volumes (MDth)	—	1,587,052	179,888	—	—	1,766,940
Average retail Home customer count (in thousands)(a)	2,878	1,856	774	—	—	5,508
Ending retail Home customer count (in thousands)(a)	2,928	2,137	762	—	—	5,827
Average Vivint Smart Home subscriber count (in thousands)(b)	—	—	—	2,008	—	2,008
Ending Vivint Smart Home subscriber count (in thousands)(b)	—	—	—	2,043	—	2,043
GWh sold	30,776	5,396	5,903	—	—	42,075
GWh generated (c)	30,776	2,016	5,903	—	—	38,695
(a)Home customer count includes recurring residential customers, services customers and community choice.
(b)Vivint Smart Home subscribers includes customers that also purchase other NRG products
(c) Includes owned and leased generation, excludes tolled generation and equity investments

	Year Ended December 31, 2022
($ in millions, except otherwise noted)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue	$	9,617	$	15,856	$	4,250	$	(1)	$	29,722
Energy revenue	111		641		466		32		1,250
Capacity revenue	—		232		40		—		272
Mark-to-market for economic hedging activities	2		(30)		(56)		1		(83)
Contract amortization	—		(40)		1		—		(39)
Other revenue(a)	327		104		5		(15)		421
Total revenue	10,057		16,763		4,706		17		31,543
Cost of fuel	(1,213)		(376)		(330)		—		(1,919)
Purchased energy and other costs of sales(b)(c)(d)	(6,379)		(14,782)		(3,804)		(19)		(24,984)
Mark-to-market for economic hedging activities	611		218		503		(1)		1,331
Contract and emissions credit amortization	—		(91)		(20)		—		(111)
Depreciation and amortization	(310)		(208)		(85)		(31)		(634)
Gross margin	$	2,766	$	1,524	$	970	$	(34)	$	5,226
Less: Mark-to-market for economic hedging activities, net	613		188		447		—		1,248
Less: Contract and emissions credit amortization, net	—		(131)		(19)		—		(150)
Less: Depreciation and amortization	(310)		(208)		(85)		(31)		(634)
Economic gross margin	$	2,463	$	1,675	$	627	$	(3)	$	4,762
(a)Includes trading gains and losses and ancillary revenues
(b)Includes capacity and emissions credits
(c)Includes $3.0 billion, $120 million and $1.1 billion of TDSP expense in Texas, East, and West/Services/Other respectively
(d)Excludes depreciation and amortization shown separately

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	Year Ended December 31, 2022
Business Metrics	Texas	East	West/Services/Other	Corporate/Eliminations	Total
Home electricity sales volume (GWh)	43,155	13,269	2,250	—	58,674
Business electricity sales volume (GWh)	38,447	47,724	10,231	—	96,402
Home natural gas retail sales volumes (MDth)	—	53,051	92,035	—	145,086
Business natural gas retail sales volumes (MDth)	—	1,618,946	154,074	—	1,773,020
Average retail Home customer count (in thousands)(a)	2,961	1,783	799	—	5,543
Ending retail Home customer count (in thousands)(a)	2,859	1,761	786	—	5,406
GWh sold	37,275	10,832	6,676	—	54,783
GWh generated(b)	37,275	7,282	6,676	—	51,233
(a)Home customer count includes recurring residential customers, services customers and community choice
(b)Includes owned and leased generation, excludes tolled generation and equity investments

The following table represents the weather metrics for 2023 and 2022:

	Year ended December 31,			Quarter ended December 31,			Quarter ended September 30,			Quarter ended June 30,			Quarter ended March 31,
Weather Metrics	Texas	East	West/Services/Other(a)	Texas	East	West/Services/Other(a)	Texas	East	West/Services/Other(a)	Texas	East	West/Services/Other(a)	Texas	East	West/Services/Other(a)
2023
CDDs(b)	3,468	1,229	2,024	285	85	158	2,039	817	1,291	978	273	502	166	54	73
HDDs(b)	1,469	4,139	2,105	613	1,520	688	—	48	4	57	479	254	799	2,092	1,159
2022
CDDs	3,417	1,340	2,133	277	72	160	1,789	874	1,268	1,283	352	674	68	42	31
HDDs	1,935	4,627	2,232	734	1,683	884	—	54	3	24	486	194	1,177	2,404	1,151
10-year average
CDDs	3,051	1,311	1,939	290	91	163	1,673	824	1,173	986	356	557	102	40	46
HDDs	1,715	4,766	2,064	665	1,642	774	5	52	9	67	547	188	978	2,525	1,093

(a)The West/Services/Other weather metrics are comprised of the average of the CDD and HDD regional results for the West - California and West - South Central regions

(b)National Oceanic and Atmospheric Administration-Climate Prediction Center - A Cooling Degree Day ("CDD"), represents the number of degrees that the mean temperature for a particular day is above 65 degrees Fahrenheit in each region. A Heating Degree Day ("HDD"), represents the number of degrees that the mean temperature for a particular day is below 65 degrees Fahrenheit in each region. The CDDs/HDDs for a period of time are calculated by adding the CDDs/HDDs for each day during the period

51

Gross margin and economic gross margin

Gross margin decreased $2.3 billion and economic gross margin increased $2.3 billion, both of which include intercompany sales, during the year ended December 31, 2023, compared to the same period in 2022. The detail by segment is as follows:

Texas

	(In millions)
Higher gross margin due to the net effect of: •a 15%, or $548 million, decrease in cost to serve the retail load, primarily driven by lower supply costs which were a result of lower realized power pricing, the diversified supply strategy and improved plant performance coupled with the 2022 impact of the W.A. Parish Unit 8 extended outage that began in May 2022, net of business interruption insurance proceeds; and •increased net revenue rates of $5.45 per MWh, or $523 million, partially offset by changes in customer term, product and mix of $61 million	$	1,010
Lower gross margin due to a decrease in load of 1.5 TWhs from weather	(58)
Higher gross margin from market optimization activities	33
Other	(20)
Increase in economic gross margin	$	965
Decrease in mark-to-market for economic hedging primarily due to net unrealized gains/losses on open positions related to economic hedges	(298)
Increase in contract and emissions credit amortization	(11)
Decrease in depreciation and amortization	16
Increase in gross margin	$	672

East

	(In millions)
Lower gross margin due to a decrease in generation and capacity as a result of asset retirements	$	(116)
Lower natural gas gross margin including the impact of transportation and storage contract optimization, reflects lower net revenue rates from changes in customer term, product and mix of $2.35 per Dth, or $3.86 billion, partially offset by lower supply costs of $2.30 per Dth, or $3.78 billion	(82)
Lower gross margin from the sales of NOx emissions credits	(24)
Lower natural gas gross margin from a decrease in load of 6.9 MMDth due to weather and changes in customer mix	(16)
Lower electric gross margin from a decrease in load of 686 GWhs primarily due to weather	(16)
Higher electric gross margin due to higher net revenue rates as a result of changes in customer term, product and mix of $2.50 per MWh, or $155 million, as well as lower supply costs of $1.50 per MWh, or $86 million driven primarily by decreases in power prices	241
Higher gross margin due to an increase in average realized pricing and a decrease in supply costs at Midwest Generation, offset by lower gross margin as a result of a 74% decrease in generation volumes due to dark spread contractions	56
Higher gross margin primarily due to net capacity performance penalties resulting from Winter Storm Elliott in 2022 and an increase in NYISO capacity pricing, partially offset by a decrease in PJM capacity prices	16
Other	(7)
Increase in economic gross margin	$	52
Decrease in mark-to-market for economic hedging primarily due to net unrealized gains/losses on open positions related to economic hedges	(2,602)
Decrease in contract amortization	31
Decrease in depreciation and amortization	92
Decrease in gross margin	$	(2,427)

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West/Services/Other

	(In millions)
Lower gross margin at Cottonwood driven by lower average realized power prices, planned outages in 2023 and capacity performance bonus resulting from PJM Winter Storm Elliott in 2022	$	(76)
Lower gross margin primarily due to lower Services sales	(51)
Lower electric gross margin due to an increase in supply costs of $6.50 per MWh, or $82 million, partially offset by higher revenue rates of $5.25 per MWh, or $64 million, and changes in customer mix of $2 million	(16)
Higher gross margin from market optimization activities	28
Higher natural gas gross margin due to a decrease in supply costs of $0.90 per Dth, or $228 million, and changes in customer mix of $4 million, partially offset by lower revenue rates of $0.85 per Dth, or $218 million	14
Decrease in economic gross margin	$	(101)
Decrease in mark-to-market for economic hedges primarily due to net unrealized gains/losses on open positions related to economic hedges	(1,211)
Decrease in contract amortization	5
Increase in depreciation and amortization	(10)
Decrease in gross margin	$	(1,317)

Vivint Smart Home(a)

	(In millions)
Increase due to the acquisition of Vivint Smart Home	$	1,396
Increase in economic gross margin	$	1,396
Increase in depreciation and amortization	(586)
Increase in gross margin	$	810

(a) Includes results of operations following the acquisition date of March 10, 2023

Mark-to-market for Economic Hedging Activities

Mark-to-market for economic hedging activities includes asset-backed hedges that have not been designated as cash flow hedges. Total net mark-to-market results decreased by $4.1 billion during the year ended December 31, 2023, compared to the same period in 2022.

The breakdown of gains and losses included in revenues and operating costs and expenses by segment is as follows:

	Year Ended December 31, 2023
(In millions)	Texas		East		West/Services/Other		Eliminations		Total
Mark-to-market results in revenues
Reversal of previously recognized unrealized (gains)/losses on settled positions related to economic hedges	$	—	$	(25)	$	56	$	(12)	$	19
Reversal of acquired (gain) positions related to economic hedges	—		(2)		—		—		(2)
Net unrealized gains on open positions related to economic hedges	—		84		47		(4)		127
Total mark-to-market gains in revenues	$	—	$	57	$	103	$	(16)	$	144
Mark-to-market results in operating costs and expenses
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$	(473)	$	(812)	$	(480)	$	12	$	(1,753)
Reversal of acquired loss/(gain) positions related to economic hedges	17		11		(6)		—		22
Net unrealized gains/(losses) on open positions related to economic hedges	771		(1,670)		(381)		4		(1,276)
Total mark-to-market gains/(losses) in operating costs and expenses	$	315	$	(2,471)	$	(867)	$	16	$	(3,007)

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	Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Eliminations		Total
Mark-to-market results in revenues
Reversal of previously recognized unrealized losses/(gains) on settled positions related to economic hedges	$	2	$	(5)	$	40	$	(8)	$	29
Reversal of acquired (gain) positions related to economic hedges	—		(3)		—		—		(3)
Net unrealized (losses) on open positions related to economic hedges	—		(22)		(96)		9		(109)
Total mark-to-market gains/(losses) in revenues	$	2	$	(30)	$	(56)	$	1	$	(83)
Mark-to-market results in operating costs and expenses
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$	(366)	$	(738)	$	(165)	$	8	$	(1,261)
Reversal of acquired loss/(gain) positions related to economic hedges	29		(5)		(19)		—		5
Net unrealized gains on open positions related to economic hedges	948		961		687		(9)		2,587
Total mark-to-market gains in operating costs and expenses	$	611	$	218	$	503	$	(1)	$	1,331

Mark-to-market results consist of unrealized gains and losses on contracts that are yet to be settled. The settlement of these transactions is reflected in the same revenue or cost caption as the items being hedged.

The reversals of acquired gain or loss positions were valued based upon the forward prices on the acquisition date.

For the year ended December 31, 2023, the $144 million gain in revenues from economic hedge positions was driven by an increase in the value of open positions as a result of decreases in power prices. The $3.0 billion loss in operating costs and expenses from economic hedge positions was driven primarily by the reversal of previously recognized unrealized gains on contracts that settled during the period, as well as a decrease in the value of East and West/Other open positions as a result of decreases in natural gas and power prices. This was partially offset by an increase in the value of Texas open positions as a result of increases in ERCOT power prices.

For the year ended December 31, 2022, the $83 million loss in revenues from economic hedge positions was driven by a decrease in the value of open positions as a result of increases in power prices across all segments, partially offset by the reversal of previously recognized unrealized losses on contracts that settled during the period. The $1.3 billion gain in operating costs and expenses from economic hedge positions was driven primarily by an increase in the value of open positions as a result of increases in natural gas and power prices across all segments partially offset by the reversal of previously recognized unrealized gains on contracts that settled during the period.

In accordance with ASC 815, the following table represents the results of the Company's financial and physical trading of energy commodities for the years ended December 31, 2023 and 2022. The realized and unrealized financial and physical trading results are included in revenue. The Company's trading activities are subject to limits within the Company's Risk Management Policy.

	Year ended December 31,
(In millions)	2023		2022
Trading gains/(losses)
Realized	$	11	$	6
Unrealized	38		(4)
Total trading gains	$	49	$	2

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Operations and Maintenance Expenses

Operations and maintenance expenses are comprised of the following:

(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate		Eliminations		Total
Year Ended December 31, 2023	$	624	$	345	$	245	$	187	$	—	$	(4)	$	1,397
Year Ended December 31, 2022	749		391		214		—		1		(3)		1,352

(a) Includes results of operations following the acquisition date of March 10, 2023

Operations and maintenance expenses increased by $45 million for the year ended December 31, 2023, compared to the same period in 2022, due to the following:

	(In millions)
Increase due to the acquisition of Vivint Smart Home	$	187
Increase in retail operation personnel costs primarily driven by an increase in accruals as part of the Company's annual incentive plan reflecting financial outperformance for the year	48
Increase in major maintenance expenditures associated with the scope and duration of outages at the Texas gas facilities and Cottonwood, partially offset by the Texas coal facilities (excluding W.A. Parish Unit 8 included below)	21
Decrease due to the current year partial property insurance claim for the extended outage at W.A. Parish Unit 8, as well as restoration expenses incurred in 2022, partially offset by the prior year Limestone property insurance claim	(124)
Decrease driven by the disposition of STP and Gregory in 2023	(28)
Decrease in variable operation and maintenance expense due to a reduction in PJM generation volumes in 2023	(26)
Decrease due to change in estimates of environmental remediation costs at deactivated sites in the East in 2022	(23)
Decrease driven primarily by East asset retirements, partially offset by an increase in deactivation costs in the West	(8)
Other	(2)
Increase in operations and maintenance expense	$	45

Other Cost of Operations

Other Cost of operations are comprised of the following:

(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Total
Year Ended December 31, 2023	$	243	$	131	$	13	$	3	$	390
Year Ended December 31, 2022	246		149		16		—		411

(a) Includes results of operations following the acquisition date of March 10, 2023

Other cost of operations decreased by $21 million for the year ended December 31, 2023, compared to the same period in 2022, due to the following:

	(In millions)
Decrease due to changes in current year ARO cost estimates, primarily at Jewett Mine	$	(28)
Decrease in retail gross receipt taxes due to lower revenue in the East offset by higher revenues in Texas	(10)
Decrease driven by the disposition of STP and Gregory in 2023	(5)
Increase due to higher property insurance premiums	18
Other	4
Decrease in other cost of operations	$	(21)

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Depreciation and Amortization

Depreciation and amortization expenses are comprised of the following:

(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate		Total
Year Ended December 31, 2023	$	294	$	116	$	95	$	586	$	36	$	1,127
Year Ended December 31, 2022	310		208		85		—		31		634

(a) Includes results of operations following the acquisition date of March 10, 2023

Depreciation and amortization expense increased by $493 million for the year ended December 31, 2023, compared to the same period in 2022, primarily due to higher amortization of intangible assets due to the acquisition of Vivint Smart Home in March 2023, partially offset by lower depreciation at Midwest Generation as a result of asset impairments and retirements in 2022.

Impairment Losses

During the year ended December 31, 2023, the Company recorded impairment losses related to property plant and equipment and leases of $2 million, $4 million and $20 million in the Texas, East and West/Services/Other segments, respectively.

During the year ended December 31, 2022, the Company recorded impairment losses of $206 million, of which $150 million were related to the decline in PJM capacity prices and the near-term retirement date of the Joliet facility, $43 million related to the purchase and sale agreement for the sale of the land and related assets at the Astoria generating site and the planned withdrawal and cancellation of its proposed Astoria redevelopment project, and an additional $13 million in the East segment.

Refer to Item 15 — Note 11, Asset Impairments, to the Consolidated Financial Statements for further discussion.

Selling, General and Administrative Costs

Selling, general and administrative costs are comprised of the following:

(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate/ Eliminations		Total
Year Ended December 31, 2023	$	637	$	573	$	202	$	499	$	57	$	1,968
Year Ended December 31, 2022	559		428		202		—		39		1,228

(a) Includes results of operations following the acquisition date of March 10, 2023

Selling, general and administrative costs increased by $740 million for the year ended December 31, 2023 compared to the same period in 2022, due to the following:

	(In millions)
Increase due to the acquisition of Vivint Smart Home	$	499
Increase in personnel costs primarily driven by an increase in accruals as part of the Company's annual incentive plan reflecting financial outperformance for the year	140
Increase in broker fee and commissions expenses	49
Increase in marketing and media expenses	28
Increase in consulting and legal expenses	17
Other	7
Increase in selling, general and administrative costs	$	740

Provision for Credit Losses

Provision for credit losses are comprised of the following:

(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Total
Year Ended December 31, 2023	$	159	$	28	$	30	$	34	$	251
Year Ended December 31, 2022	(40)		28		23		—		11

(a) Includes results of operations following the acquisition date of March 10, 2023

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Provision for credit losses increased by $240 million for the year ended December 31, 2023, compared to the same period in 2022, due to the following:

	(In millions)
Increase due to Winter Storm Uri loss mitigation recognized as income in 2022	$	126
Increase due to higher Home retail revenues, deteriorated customer payment behavior and the longer duration of the Texas disconnect moratorium in 2023 as compared to 2022	80
Increase due to the acquisition of Vivint Smart Home	34
Increase in provision for credit losses	$	240

Acquisition-Related Transaction and Integration Costs

Acquisition-related transaction and integration costs were $119 million and $52 million for the years ended December 31, 2023 and 2022, respectively, include:

	As of December 31,
(In millions)	2023		2022
Vivint Smart Home acquisition costs	$	38	$	17
Vivint Smart Home integration costs	52		—
Other integration costs, primarily related to Direct Energy	29		35
Acquisition-related transaction and integration costs	$	119	$	52

Gain on Sale of Assets

The gain on sale of assets of $1.6 billion and $52 million recorded for the years ended December 31, 2023 and 2022, respectively, include:

	As of December 31,
(In millions)	2023		2022
Sale of the Company's 44% equity interest in STP	$	1,236	$	—
Sale of Astoria land and related assets	199		—
Sale of the Company's 100% ownership in the Gregory natural gas generating facility	82		—
Sale of the Company's 49% ownership in the Watson natural gas generating facility	—		46
Sale of land and structures at the Company's deactivated Norwalk Harbor, LLC site	38		—
Sale of the Company's 50% ownership in Petra Nova	—		22
Sale of land at the Company's Indian River Power, LLC site	19		—
Other asset sales	4		(16)
Gain on sale of assets	$	1,578	$	52

Impairment Losses on Investments

During the year ended December 31, 2023, the Company recorded other-than-temporary impairment losses of $102 million on the Company's equity method investment in Gladstone generation facility in Queensland, Australia, as further described in Item 15 — Note 11, Asset Impairments, to the Consolidated Financial Statements.

Gain on Debt Extinguishment

A gain on debt extinguishment of $109 million was recorded for the year ended December 31, 2023, driven by a partial redemption of the 3.875% Senior Notes, due 2032, as further discussed in Item 15 — Note 13, Long-term Debt and Finance Leases, to the Consolidated Financial Statements.

Interest Expense

Interest expense increased by $250 million for the year ended December 31, 2023, compared to the same period in 2022, primarily due to the Vivint Smart Home acquisition including the impact of newly issued Senior Secured First Lien Notes, the acquired debt of Vivint Smart Home, the borrowings on the Revolving Credit Facility and the Receivables Securitization Facilities, as well as the write-off of the deferred financing costs associated with the cancellation of the bridge facility.

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Income Tax Expense

For the year ended December 31, 2023, NRG recorded an income tax benefit of $11 million on a pre-tax loss of $213 million. For the same period in 2022, NRG recorded income tax expense of $442 million on pre-tax income of $1.7 billion. The effective tax rate was 5.2% and 26.6% for the years ended December 31, 2023 and 2022, respectively.

For the year ended December 31, 2023, NRG's overall effective tax rate was lower than the federal statutory tax rate of 21%, primarily due to permanent differences and changes in state valuation allowances.

	Year Ended December 31,
(In millions, except effective income tax rate)	2023			2022
(Loss)/Income before income taxes	$	(213)		$	1,663
Tax at federal statutory tax rate	(45)			349
State taxes	(22)			69
Foreign rate differential	(10)			7
Changes in state valuation allowances	42			(3)
Permanent differences	31			17
Recognition of uncertain tax benefits	12			8
Deferred impact of state tax rate changes	3			14
Foreign tax refunds	(17)			—
Return to provision adjustments	(5)			—
Carbon capture tax credits	—			(19)
Income tax (benefit)/expense	$	(11)		$	442
Effective income tax rate	5.2		%	26.6		%

The effective income tax rate may vary from period to period depending on, among other factors, the geographic and business mix of earnings and losses and changes in valuation allowances in accordance with ASC 740, Income Taxes ("ASC 740"). These factors and others, including the Company's history of pre-tax earnings and losses, are taken into account in assessing the ability to realize deferred tax assets.

Liquidity and Capital Resources

Liquidity Position

As of December 31, 2023 and 2022, NRG's liquidity, excluding collateral funds deposited by counterparties, was approximately $4.8 billion and $2.8 billion, respectively, comprised of the following:

	As of December 31,
(In millions)	2023		2022
Cash and cash equivalents	$	541	$	430
Restricted cash - operating	21		5
Restricted cash - reserves (a)	3		35
Total	565		470
Total availability under Revolving Credit Facility and collective collateral facilities(b)	4,278		2,324
Total liquidity, excluding collateral funds deposited by counterparties	$	4,843	$	2,794

(a)Includes reserves primarily for debt service, performance obligations and capital expenditures

(b)Total capacity of Revolving Credit Facility and collective collateral facilities was $7.4 billion and $6.4 billion as of December 31, 2023 and December 31, 2022, respectively

As of December 31, 2023, total liquidity, excluding collateral funds deposited by counterparties, increased by $2.0 billion. Changes in cash and cash equivalent balances are further discussed under the heading Cash Flow Discussion. Cash and cash equivalents at December 31, 2023, were predominantly held in bank deposits.

Management believes that the Company's liquidity position and cash flows from operations will be adequate to finance operating and maintenance capital expenditures, to fund dividends, and to fund other liquidity commitments in the short and long-term. Management continues to regularly monitor the Company's ability to finance the needs of its operating, financing and investing activity within the dictates of prudent balance sheet management.

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The consolidated statement of cash flows includes certain draws from, and payments to, the revolving credit facility and other credit facilities which are not eligible for net reporting. These transactions are for short term liquidity purposes.

Credit Ratings

On March 1, 2023, following the Vivint Smart Home acquisition financing launch, Standard and Poor's downgraded the Company's issuer credit to BB with a Stable outlook from BB+. There was no change to Moody's and Fitch ratings at the time.

The following table summarizes the Company's current credit ratings:

	S&P	Moody's	Fitch
NRG Energy, Inc.	BB Stable	Ba1 Stable	BB+ Stable
3.75% Senior Secured Notes, due 2024	BBB-	Baa3	BBB-
2.00% Senior Secured Notes, due 2025	BBB-	Baa3	BBB-
2.45% Senior Secured Notes, due 2027	BBB-	Baa3	BBB-
6.625% Senior Notes, due 2027	BB	Ba2	BB+
6.75% Vivint Smart Home Senior Secured Notes, due 2027	BB	Ba2	n/a
5.75% Senior Notes, due 2028	BB	Ba2	BB+
3.375% Senior Notes, due 2029	BB	Ba2	BB+
4.45% Senior Secured Notes, due 2029	BBB-	Baa3	BBB-
5.25% Senior Notes, due 2029	BB	Ba2	BB+
5.75% Vivint Smart Home Senior Notes, due 2029	B	Ba3	n/a
3.625% Senior Notes, due 2031	BB	Ba2	BB+
3.875% Senior Notes, due 2032	BB	Ba2	BB+
7.00% Senior Secured Notes, due 2033	BBB-	Baa3	BBB-
Revolving Credit Facility, due 2028	BBB-	Baa3	BBB-
Vivint Smart Home Senior Secured Term Loan, due 2028	BB	Ba2	n/a

Liquidity

The principal sources of liquidity for NRG's operating and capital expenditures are expected to be derived from cash on hand, cash flows from operations and financing arrangements. As described in Item 15 — Note 13, Long-term Debt and Finance Leases, to the Consolidated Financial Statements, the Company's financing arrangements consist mainly of the Senior Notes, Convertible Senior Notes, Senior Secured First Lien Notes, Revolving Credit Facility, the Receivables Securitization Facilities and tax-exempt bonds. The Company also issues letters of credit through bilateral letter of credit facilities and the P-Caps letter of credit facility. As part of the acquisition of Vivint Smart Home on March 10, 2023, NRG acquired Vivint Smart Home's existing debt, which includes senior secured notes, senior notes and a senior secured term-loan.

The Company's requirements for liquidity and capital resources, other than for operating its facilities, can generally be categorized by the following: (i) market operations activities; (ii) debt service obligations, as described more fully in Item 15 — Note 13, Long-term Debt and Finance Leases, to the Consolidated Financial Statements; (iii) capital expenditures, including maintenance, environmental, and investments and integration; and (iv) allocations in connection with acquisition opportunities, debt repayments, share repurchases and dividend payments to stockholders, as described in Item 15 — Note 16, Capital Structure, to the Consolidated Financial Statements.

The Company remains committed to maintaining a strong balance sheet and continues to work to achieve investment grade credit metrics over time primarily through debt reduction and the realization of growth initiatives.

Sale of the 44% equity interest in STP

On November 1, 2023, the Company closed on the sale of its 44% equity interest in STP to Constellation. Proceeds of $1.75 billion were reduced by working capital and other adjustments of $96 million, resulting in net proceeds of $1.654 billion.

Sale of Gregory

On October 2, 2023, the Company closed on the sale of its 100% ownership in the Gregory natural gas generating facility in Texas for $102 million.

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Debt Reduction

During 2023, the Company reduced its debt by $900 million using funds from cash from operations. Additionally, the Company redeemed $620 million in aggregate principal amount of its 3.875% Senior Notes, due 2032, for $502 million using a portion of the proceeds from the sale of STP.

The Company intends to spend approximately $500 million reducing debt during 2024 to maintain its targeted credit metrics. The Company intends to fund the debt reduction from cash from operations.

Vivint Smart Home Acquisition

On March 10, 2023, the Company completed the acquisition of Vivint Smart Home. The Company paid $12 per share, or $2.6 billion in cash. The Company funded the acquisition using a combination of $740 million in newly-issued secured corporate debt, $650 million in newly-issued preferred stock, $900 million drawn from its Revolving Credit Facility and Receivables Facilities, and cash on hand.

Issuance of 2033 Senior Notes

On March 9, 2023, the Company issued $740 million of aggregate principal amount of 7.000% senior notes due 2033. The 2033 Senior Notes are senior secured obligations of NRG and are guaranteed by certain of its subsidiaries. Interest is paid semi-annually beginning on September 15, 2023 until the maturity date of March 15, 2033. For further discussion, see Note 13, Long-term Debt and Finance Leases.

Series A Preferred Stock

On March 9, 2023, the Company issued 650,000 shares of 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock. For further discussion, see Note 16, Capital Structure.

Revolving Credit Facility

On February 14, 2023, the Company amended its Revolving Credit Facility to: (i) increase the existing revolving commitments thereunder by $600 million, (ii) extend the maturity date of a portion of the revolving commitments thereunder to February 14, 2028, (iii) transition the benchmark rate applicable to revolving loans from LIBOR to SOFR and (iv) make certain other amendments to the terms of the Revolving Credit Facility for purposes of, among other things, providing additional flexibility.

On March 13, 2023, the Company further amended its Revolving Credit Facility to increase the existing revolving commitments by an additional $45 million. As of December 31, 2023, there were no outstanding borrowings and there were $883 million in letters of credit issued under the Revolving Credit Facility.

Receivables Securitization Facilities

On June 22, 2023, NRG Receivables amended its existing Receivables Facility to, among other things, (i) extend the scheduled termination date to June 21, 2024, (ii) increase the aggregate commitments from $1.0 billion to $1.4 billion (adjusted seasonally) and (iii) add a new originator. On October 6, 2023, the Receivables Facility was further amended to replace the benchmark interest rate of the Receivable Facility's subordinated note from LIBOR to SOFR. As of December 31, 2023, there were no outstanding borrowings and there were $1.0 billion in letters of credit issued.

In addition, in connection with the amendments to the Receivables Facility, on June 22, 2023, the Company and the originators thereunder renewed the existing uncommitted Repurchase Facility that provides short-term financing secured by a subordinated note issued by NRG Receivables LLC. Such renewal, among other things, extends the maturity date to June 21, 2024 and joins an additional originator to the Repurchase Facility. On October 6, 2023, the Repurchase Facility was further amended to reflect the concurrent amendment to the Receivables Facility's subordinated note. As of December 31, 2023, there were no outstanding borrowings.

Bilateral Letter of Credit Facilities

On May 19, 2023, May 30, 2023 and October 17, 2023 the Company increased the size of its bilateral letter of credit facilities by $25 million, $100 million and $50 million, respectively, to provide additional liquidity, allowing for the issuance of up to $850 million of letters of credit. These facilities are uncommitted. As of December 31, 2023, $671 million was issued under these facilities.

Pre-Capitalized Trust Securities Facility

On August 29, 2023, the Company entered into a Facility Agreement with the Trust, in connection with the sale by the Trust of $500 million P-Caps. The P-Caps are to be redeemed by the Trust on July 31, 2028 or earlier upon an early redemption of the P-Caps Secured Notes. The P-Caps replaced the Company’s existing pre-capitalized trust securities redeemable 2023 issued by Alexander Funding Trust, which matured on November 15, 2023.

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The Facility Agreements allows for the issuance of the P-Caps Secured Notes by the Company to the Trust. In addition, the Company entered into a LC Agreement for the issuance of letters of credit in an aggregate amount not to exceed $485 million.

Sale of Astoria

On January 6, 2023, the Company closed on the sale of land and related assets from the Astoria site, within the East region of operations, for proceeds of $212 million, subject to transactions fees of $3 million and certain indemnifications. As part of the transaction, NRG entered into an agreement to lease the land back for the purpose of operating the Astoria gas turbines. Decommissioning was completed in December 2023 and the lease agreement has been terminated.

Pension and Other postretirement benefit contributions

As of December 31, 2023, the Company’s estimated pension minimum funding requirements for the next 5 years were $142 million, of which $43 million are required to be made within the next 12 months. As of December 31, 2023, the Company’s estimated other postretirement benefits minimum funding requirements for the next 5 years were $28 million, of which $6 million are required to be made within the next 12 months. These amounts represent estimates based on assumptions that are subject to change. For further discussion, see Item 15 — Note 15, Benefit Plans and Other Postretirement Benefits, to the Consolidated Financial Statements.

Debt Service Obligations

Principal payments on debt and finance leases as of December 31, 2023, are due in the following periods:

(In millions)
Description	2024		2025		2026		2027		2028		Thereafter		Total
Recourse Debt:
Senior Notes, due 2027	$	—	$	—	$	—	$	375	$	—	$	—	$	375
Senior Notes, due 2028	—		—		—		—		821		—		821
Senior Notes, due 2029	—		—		—		—		—		733		733
Senior Notes, due 2029	—		—		—		—		—		500		500
Senior Notes, due 2031	—		—		—		—		—		1,030		1,030
Senior Notes, due 2032	—		—		—		—		—		480		480
Convertible Senior Notes, due 2048	—		—		—		—		—		575		575
Senior Secured First Lien Notes, due 2024	600		—		—		—		—		—		600
Senior Secured First Lien Notes, due 2025	—		500		—		—		—		—		500
Senior Secured First Lien Notes, due 2027	—		—		—		900		—		—		900
Senior Secured First Lien Notes, due 2029	—		—		—		—		—		500		500
Senior Secured First Lien Notes, due 2033	—										740		740
Tax-exempt bonds	—		247		—		—		59		160		466
Subtotal Recourse Debt	600		747		—		1,275		880		4,718		8,220
Non-Recourse Debt:
Vivint Smart Home Senior Secured Notes, due 2027	—		—		—		600		—		—		600
Vivint Smart Home Senior Notes, due 2029	—		—		—		—		—		800		800
Vivint Smart Home Senior Secured Term Loan, due 2028	14		14		14		14		1,264		—		1,320
Subtotal Vivint Smart Home Non-Recourse Debt	14		14		14		614		1,264		800		2,720
Subtotal Debt	614		761		14		1,889		2,144		5,518		10,940
Finance Leases:
Finance leases	6		8		2		1		1		1		19
Total Debt and Finance Leases	$	620	$	769	$	16	$	1,890	$	2,145	$	5,519	$	10,959
Interest Payments	$	609	$	595	$	587	$	521	$	403	$	806	$	3,521

For further discussion, see Item 15 — Note 13, Long-term Debt and Finance Leases.

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Market Operations

The Company's market operations activities require a significant amount of liquidity and capital resources. These liquidity requirements are primarily driven by: (i) margin and collateral posted with counterparties; (ii) margin and collateral required to participate in physical markets and commodity exchanges; (iii) timing of disbursements and receipts (e.g. buying power before receiving retail revenues); and (iv) initial collateral for large structured transactions. As of December 31, 2023, market operations had total cash collateral outstanding of $441 million and $3.1 billion outstanding in letters of credit to third parties primarily to support its market activities. As of December 31, 2023, total funds deposited by counterparties were $84 million in cash and $478 million of letters of credit.

The Company has entered into long-term contractual arrangements related to energy purchases, gas transportation and storage, and fuel and transportation services. As of December 31, 2023, the Company had minimum payment obligations under such outstanding agreements of $3.4 billion, with $573 million payable within the next 12 months and an additional $978 million of short-term purchase energy commitments. For further discussion, see Item 15 — Note 23, Commitments and Contingencies.

Future liquidity requirements may change based on the Company's hedging activities and structures, fuel purchases, and future market conditions, including forward prices for energy and fuel and market volatility. In addition, liquidity requirements are dependent on the Company's credit ratings and general perception of its creditworthiness.

First Lien Structure

NRG has the capacity to grant first liens to certain counterparties on a substantial portion of the Company's assets, subject to various exclusions including NRG's assets that have project-level financing and the assets of certain non-guarantor subsidiaries, to reduce the amount of cash collateral and letters of credit that it would otherwise be required to post from time to time to support its obligations under out-of-the-money hedge agreements. The first lien program does not limit the volume that can be hedged or the value of underlying out-of-the-money positions. The first lien program also does not require NRG to post collateral above any threshold amount of exposure. The first lien structure is not subject to unwind or termination upon a ratings downgrade of a counterparty and has no stated maturity date.

The Company's first lien counterparties may have a claim on its assets to the extent market prices exceed the hedged prices. As of December 31, 2023, all hedges under the first liens were in-the-money on a counterparty aggregate basis.

Capital Expenditures

The following table summarizes the Company's capital expenditures for maintenance, environmental and growth investments for the year ended December 31, 2023:

(In millions)	Maintenance		Environmental		Investments and Integration		Total
Texas	$	455	$	3	$	37	$	495
East	4		—		1		5
West/Services/Other	21		—		6		27
Vivint Smart Home(a)	17		—		1		18
Corporate	19		—		34		53
Total cash capital expenditures for 2023	516		3		79		598
Integration operating expenses and cost to achieve	—		—		81		81
Investments	—		—		164		164
Total cash capital expenditures and investments for the year ended December 31, 2023	$	516	$	3	$	324	$	843

(a)Includes expenditures following the acquisition date of March 10, 2023

Investments and Integration for the year ended December 31, 2023, include growth expenditures, integration, small book acquisitions and other investments.

Environmental Capital Expenditures Estimate

NRG estimates that environmental capital expenditures from 2024 through 2028 required to comply with environmental laws will be approximately $66 million. The largest component is the cost of complying with ELG at the Company's coal units in Texas.

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The table below summarizes the status of NRG's coal fleet with respect to air quality controls. NRG uses an integrated approach to fuels, controls and emissions markets to meet environmental requirements.

		SO2		NOx		Mercury		Particulate
Units	State	Control Equipment	Install Date	Control Equipment	Install Date	Control Equipment	Install Date	Control Equipment	Install Date
Indian River 4	DE	CDS	2011	LNBOFA/SCR	1999/2011	ACI/CDS/FF	2008/2011	ESP/FF	1980/2011
Limestone 1-2	TX	FGD	1985-86	LNBOFA	2002/2003	ACI	2015	ESP	1985-1986
Powerton 5	IL	DSI	2016	OFA/SNCR	2003/2012	ACI	2009	ESP/upgrade	1973/2016
Powerton 6	IL	DSI	2014	OFA/SNCR	2002/2012	ACI	2009	ESP/upgrade	1976/2014
W.A. Parish 5, 6, 7	TX	FF co-benefit	1988	SCR	2004	ACI	2015	FF	1988
W.A. Parish 8	TX	FGD	1982	SCR	2004	ACI	2015	FF	1988

ACI -  Activated Carbon Injection CDS - Circulating Dry Scrubber DSI - Dry Sorbent Injection with Trona ESP - Electrostatic Precipitator FGD - Flue Gas Desulfurization (wet)
FF- Fabric Filter LNBOFA - Low NOx Burner with Overfire Air OFA - Overfire Air SCR - Selective Catalytic Reduction SNCR - Selective Non-Catalytic Reduction

The following table summarizes the estimated environmental capital expenditures by year:

(In millions)	Total
2024	$	28
2025	26
Thereafter	12
Total	$	66

Share Repurchases

In June 2023, NRG revised its long-term capital allocation policy to target allocating approximately 80% of cash available for allocation after debt reduction to be returned to shareholders. As part of the revised capital allocation framework, the Company announced an increase to its share repurchase authorization to $2.7 billion, to be executed through 2025.

On November 6, 2023, the Company executed Accelerated Share Repurchase agreements to repurchase a total of $950 million of NRG's outstanding common stock. Under the ASR, the Company paid a total of $950 million and will receive shares of NRG's common stock on specified settlement dates.

During the year ended December 31, 2023, the Company completed $1.2 billion of share repurchases, including the $950 million ASR and $200 million of open market repurchases, under the $2.7 billion authorization. See Item 15 - Note 16, Capital Structure, to the Consolidated Financial Statements for additional discussion.

Dividend Increase on Common Stock

In the first quarter of 2023, NRG increased the annual dividend on its common stock to $1.51 from $1.40 per share. The Company returned $352 million of capital to shareholders in the year ended 2023 through a $1.51 dividend per common share. In 2024, NRG further increased the annual dividend to $1.63 per share, representing an 8% increase from 2023. The Company expects to target an annual dividend growth rate of 7-9% per share in subsequent years.

On January 19, 2024, NRG declared a quarterly dividend on the Company's common stock of $0.4075 per share, or $1.63 per share on an annualized basis, payable on February 15, 2024, to stockholders of record as of February 1, 2024. The Company's common stock dividends are subject to available capital, market conditions, and compliance with associated laws and regulations.

Series A Preferred Stock Dividends

In September 2023, the Company declared and paid a semi-annual dividend of $52.96 per share on its outstanding Series A Preferred Stock, totaling $34 million. Cumulative cash dividends on the Series A Preferred Stock are payable semiannually, in arrears, on each March 15 and September 15, when, as and if declared by the Board of Directors.

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Additional Material Cash Requirements Not Discussed Above

Operating leases — The Company leases generating facilities, land, office and equipment, railcars, fleet vehicles and storefront space at retail stores. As of December 31, 2023, the Company had lease payment obligations of $311 million, of which $118 million is payable within the next 12 months. For further discussion, see Item 15 — Note 10, Leases.

Other liabilities — Other liabilities includes water right agreements, service and maintenance agreements, stadium naming rights, stadium sponsorships, long-term service agreements and other contractual obligations. As of December 31, 2023, the Company had total of $213 million under such commitments, of which $40 million are payable within the next 12 months.

Contingent obligations for guarantees — NRG and its subsidiaries enter into various contracts that include indemnifications and guarantee provisions as a routine part of the Company’s business activities. For further discussion, see Item 15 —Note 27, Guarantees.

Obligations Arising Out of a Variable Interest in an Unconsolidated Entity

Variable interest in Equity investments — NRG's investment in Ivanpah is a variable interest entity for which NRG is not the primary beneficiary. See also Item 15 — Note 17, Investments Accounted for by the Equity Method and Variable Interest Entities, to the Consolidated Financial Statements for additional discussion. NRG's pro-rata share of non-recourse debt was approximately $461 million as of December 31, 2023. This indebtedness may restrict the ability of Ivanpah to issue dividends or distributions to NRG.

Cash Flow Discussion

2023 compared to 2022

The following table reflects the changes in cash flows for the comparative years:

	Year ended December 31,
(In millions)	2023		2022		Change
Cash (used)/provided by operating activities	$	(221)	$	360	$	(581)
Cash used by investing activities	(910)		(332)		(578)
Cash (used)/provided by financing activities	(400)		1,043		(1,443)

Cash (used)/provided by operating activities

Changes to cash (used)/provided by operating activities were driven by:

	(In millions)
Increase in operating income adjusted for other non-cash items	$	2,892
Changes in cash collateral in support of risk management activities due to change in commodity prices	(2,702)
Decrease due to receipt of uplift securitization proceeds from ERCOT in 2022	(689)
Decrease in working capital primarily driven by Vivint Smart Home capitalized contract costs partially offset by deferred revenues	(361)
Increase in working capital related to accrued personnel costs primarily due to the Company's annual incentive plan reflecting financial outperformance for 2023	188
Increase in working capital related to accounts receivable and inventory primarily due to lower gas and power market pricing coupled with lower gas volumes, partially offset by a decrease in accounts payable	91
	$	(581)

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Cash used by investing activities

Changes to cash (used)/provided by investing activities were driven by:

	(In millions)
Increase in cash paid for acquisitions primarily due to the acquisition of Vivint Smart Home in March 2023	$	(2,461)
Increase in proceeds from the sale of assets primarily due to the sale of the Company's 44% equity interest in STP in November 2023	1,898
Increase from insurance proceeds for property, plant and equipment, net, in 2023	240
Increase in capital expenditures	(231)
Decrease in proceeds from sales of emissions allowances, net of purchases	(18)
Increase due to fewer purchases of investments in nuclear decommissioning trust fund securities, net of sales	(6)
	$	(578)

Cash (used)/provided by financing activities

Changes in cash (used)/provided by financing activities were driven by:

	(In millions)
Decrease in net receipts from settlement of acquired derivatives	$	(1,653)
Increase in proceeds from issuance of long-term debt in 2023	731
Increase in proceeds from issuance of preferred stock in 2023	635
Increase in share repurchase activity	(566)
Increase of repayments of long-term debt and finance leases	(518)
Increase in payments of dividends primarily due to preferred stock issued in 2023	(49)
Increase in payments of deferred issuance costs	(23)
	$	(1,443)

NOLs, Deferred Tax Assets and Uncertain Tax Position Implications

For the year ended December 31, 2023, the Company had domestic pre-tax book income of $261 million and foreign pre-tax book loss of $474 million. For the year ended December 31, 2023, the Company utilized U.S. federal NOLs of $1.9 billion, and tax credits of $73 million. As of December 31, 2023, the Company has cumulative U.S. federal NOL carryforwards of $8.4 billion, of which $6.4 billion do not have an expiration date, and cumulative state NOL carryforwards of $6.4 billion for financial statement purposes. NRG also has cumulative foreign NOL carryforwards of $411 million, most of which have no expiration date. In addition to the above NOLs, NRG has a $517 million indefinite carryforward for interest deductions, as well as $317 million of tax credits to be utilized in future years. As a result of the Company's tax position, including the utilization of federal and state NOLs, and based on current forecasts, the Company anticipates income tax payments, due to federal, state and foreign jurisdictions, of up to $160 million in 2024. There is no impact on the Company's provision for income taxes from the CAMT for the year ended December 31, 2023.

The Company has $73 million of tax effected uncertain federal, state and foreign tax benefits for which the Company has recorded a non-current tax liability of $76 million (inclusive of accrued interest) until such final resolution with the related taxing authority.

The Company is no longer subject to U.S. federal income tax examinations for years prior to 2020. With few exceptions, state and Canadian income tax examinations are no longer open for years before 2015.

Guarantor Financial Information

As of December 31, 2023, the Company's outstanding registered senior notes consisted of $375 million of the 2027 Senior Notes and $821 million of the 2028 Senior Notes, as shown in Note 13, Long-term Debt and Finance Leases. These Senior Notes are guaranteed by certain of NRG's current and future 100% owned domestic subsidiaries, or guarantor subsidiaries (the “Guarantors”). See Exhibit 22.1 for a listing of the Guarantors. These guarantees are both joint and several.

NRG conducts much of its business through and derives much of its income from its subsidiaries. Therefore, the Company's ability to make required payments with respect to its indebtedness and other obligations depends on the financial results and condition of its subsidiaries and NRG's ability to receive funds from its subsidiaries. There are no restrictions on the ability of any of the Guarantors to transfer funds to NRG. Other subsidiaries of the Company do not guarantee the registered

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debt securities of either NRG Energy, Inc. or the Guarantors (such subsidiaries are referred to as the “Non-Guarantors”). The Non-Guarantors include all of NRG's foreign subsidiaries and certain domestic subsidiaries.

The tables below present summarized financial information of NRG Energy, Inc. and the Guarantors in accordance with Rule 3-10 under the SEC's Regulation S-X. The financial information may not necessarily be indicative of results of operations or financial position of NRG Energy, Inc. and the Guarantors in accordance with U.S. GAAP.

The following table presents the summarized statement of operations:

(In millions)	For the Year Ended December 31, 2023
Revenue(a)	$	24,202
Operating income(b)	600
Total other expense	(286)
Income before income taxes	314
Net Income	182

(a)Intercompany transactions with Non-Guarantors include revenue of $9 million during the year ended December 31, 2023

(b)Intercompany transactions with Non-Guarantors including cost of operations of $50 million and selling, general and administrative of $209 million during the year ended December 31, 2023

The following table presents the summarized balance sheet information:

(In millions)	December 31, 2023
Current assets(a)	$	7,239
Property, plant and equipment, net	1,217
Non-current assets	11,843
Current liabilities(b)	7,997
Non-current liabilities	9,706

(a)Includes intercompany receivables due from Non-Guarantors of $92 million as of December 31, 2023

(b)Includes intercompany payables due to Non-Guarantors of $4 million as of December 31, 2023

Fair Value of Derivative Instruments

NRG may enter into energy purchase and sales contracts, fuel purchase contracts and other energy-related financial instruments to mitigate variability in earnings due to fluctuations in spot market prices and to hedge fuel requirements at power plants or retail load obligations. In order to mitigate interest risk associated with the issuance of the Company's variable rate debt, NRG enters into interest rate swap agreements. In addition, in order to mitigate foreign exchange rate risk primarily associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements.

Under Flex Pay, offered by Vivint Smart Home, subscribers pay for smart home products by obtaining financing from a third-party financing provider under the Consumer Financing Program. Vivint Smart Home pays certain fees to the financing providers and shares in credit losses depending on the credit quality of the subscriber.

NRG's trading activities are subject to limits in accordance with the Company's Risk Management Policy. These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative financial instruments are recognized in earnings.

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The tables below disclose the activities that include both exchange and non-exchange traded contracts accounted for at fair value in accordance with ASC 820, Fair Value Measurements and Disclosures ("ASC 820"). Specifically, these tables disaggregate realized and unrealized changes in fair value; disaggregate estimated fair values at December 31, 2023, based on their level within the fair value hierarchy defined in ASC 820; and indicate the maturities of contracts at December 31, 2023. For a full discussion of the Company's valuation methodology of its contracts, see Derivative Fair Value Measurements in Item 15 — Note 5, Fair Value of Financial Instruments, to the Consolidated Financial Statements.

Derivative Activity Gains/(Losses)	(In millions)
Fair value of contracts as of December 31, 2022	$	3,553
Contracts realized or otherwise settled during the period	(1,629)
Vivint Smart Home contracts acquired during the period	(112)
Other changes in fair value	(1,164)
Fair value of contracts as of December 31, 2023	$	648

	Fair Value of Contracts as of December 31, 2023
(In millions)	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
Level 1	$	(120)	$	45	$	(5)	$	1	$	(79)
Level 2	(2)		424		172		148		742
Level 3	(35)		19		(3)		4		(15)
Total	$	(157)	$	488	$	164	$	153	$	648

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. Also, collateral received or posted on the Company's derivative assets or liabilities are recorded on a separate line item on the balance sheet. Consequently, the magnitude of the changes in individual current and non-current derivative assets or liabilities is higher than the underlying credit and market risk of the Company's portfolio. As discussed in Item 7A — Quantitative and Qualitative Disclosures About Market Risk, Commodity Price Risk, NRG measures the sensitivity of the Company's portfolio to potential changes in market prices using VaR, a statistical model which attempts to predict risk of loss based on market price and volatility. NRG's risk management policy places a limit on one-day holding period VaR, which limits the Company's net open position. As the Company's trade-by-trade derivative accounting results in a gross-up of the Company's derivative assets and liabilities, the net derivative assets and liability position is a better indicator of NRG's hedging activity. As of December 31, 2023, NRG's net derivative asset was $648 million, a decrease to total fair value of $2.9 billion as compared to December 31, 2022. This decrease was primarily driven by roll-off of trades that settled during the period, losses in fair value, and Vivint Smart Home contracts acquired during the period.

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 result in a change of approximately $2.0 billion in the net value of derivatives as of December 31, 2023.

Critical Accounting 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 appropriate technical accounting rules and guidance 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 accounting guidance has not changed.

NRG evaluates these estimates, on an ongoing basis, 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 estimates as those that are the most pervasive and important to the portrayal of the Company's financial position and results of operations, and require the most difficult, subjective, and/or complex judgments by management about matters that are inherently uncertain.

Such accounting estimates include:

Accounting Estimate	Judgments/Uncertainties Affecting Application
Derivative Instruments	Assumptions used in valuation techniques
	Market maturity and economic conditions
	Contract interpretation
	Market conditions in the energy industry, especially the effects of price volatility on contractual commitments
Income Taxes and Valuation Allowance for Deferred Tax Assets	Interpret existing tax statute and regulations upon application to transactions
	Ability to utilize tax benefits through carry backs to prior periods and carry forwards to future periods
Evaluation of Assets for Impairment	Regulatory and political environments and requirements
	Estimated useful lives of assets
	Environmental obligations and operational limitations
	Estimates of future cash flows
	Estimates of fair value
	Judgment about impairment triggering events
Goodwill and Other Intangible Assets	Estimated useful lives for finite-lived intangible assets
	Judgment about impairment triggering events
	Estimates of reporting unit's fair value
	Fair value estimate of intangible assets acquired in business combinations
Business Combinations	Fair value of assets acquired and liabilities assumed in business combinations
	Estimated future cash flow
	Estimated useful lives of assets
Contingencies	Estimated financial impact of event(s)
	Judgment about likelihood of event(s) occurring
	Regulatory and political environments and requirements

Derivative Instruments

The Company follows the guidance of ASC 815, Derivatives and Hedging "(ASC 815"), to account for derivative instruments. ASC 815 requires the Company to mark-to-market all derivative instruments on the balance sheet and recognize fair value change in earnings, unless they qualify for the NPNS exception. ASC 815 applies to NRG's energy related commodity contracts, interest rate swaps, foreign exchange contracts and Consumer Financing Program.

Energy-Related Commodities

As of December 31, 2023, for purposes of measuring the fair value of derivative instruments, the Company primarily uses quoted exchange prices and consensus pricing. Consensus pricing is provided by independent pricing services which are compiled from market makers with longer dated tenors as compared to broker quotes. Prior to the fourth quarter of 2023, the Company valued derivatives based on price quotes from brokers in active markets who regularly facilitate those transactions. The Company started using consensus pricing as it offers data from more market makers and for longer dated tenors as compared to broker quotes, enhances data integrity, and increases transparency. When external prices are not available, NRG uses internal models to determine the fair value. These internal models include assumptions of the future prices of energy commodities based on the specific market in which the energy commodity is being purchased or sold, using externally available forward market pricing curves for all periods possible under the pricing model. These estimations are considered to be critical accounting estimates.

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Interest Rate Swaps

NRG is exposed to changes in interest rate through the Company's issuance of variable rate debt. To manage the Company's interest rate risk, NRG enters into interest rate swap agreements. In order to qualify the derivative instruments for hedged transactions, NRG estimates the forecasted borrowings for interest rate swaps occurring within a specified time period.

Foreign Exchange Contracts

In order to mitigate foreign exchange risk primarily associated with the purchase of USD denominated natural gas for the Company's Canadian business, the Company enters into foreign exchange contract agreements.

Consumer Financing Program

The derivative positions for the Company's Consumer Financing Program are valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates. In summary, the fair value represents an estimate of the present value of the cash flows Vivint Smart Home will be obligated to pay to the third-party financing provider for each component of the derivative.

Certain derivative instruments that meet the criteria for derivative accounting treatment also qualify for a scope exception to derivative accounting, as they are considered to be NPNS. The availability of this exception is based upon the assumption that the Company has the ability and it is probable to deliver or take delivery of the underlying item. These assumptions are based on expected load requirements, internal forecasts of sales and generation and historical physical delivery on contracts. Derivatives that are considered to be NPNS are exempt from derivative accounting treatment and are accounted for under accrual accounting. If it is determined that a transaction designated as NPNS no longer meets the scope exception due to changes in estimates, the related contract would be recorded on the balance sheet at fair value combined with the immediate recognition through earnings.

Income Taxes and Valuation Allowance for Deferred Tax Assets

As of December 31, 2023, NRG’s deferred tax assets were primarily the result of U.S. federal and state NOLs, the difference between book and tax basis in property, plant, and equipment, deferred revenues and tax credit carryforwards. The realization of deferred tax assets is dependent upon the Company's ability to generate sufficient future taxable income during the periods in which those temporary differences become deductible, prior to the expiration of the tax attributes. The evaluation of deferred tax assets requires judgment in assessing the likely future tax consequences of events that have been recognized in the Company's financial statements or tax returns and forecasting future profitability by tax jurisdiction.

The Company evaluates its deferred tax assets quarterly on a jurisdictional basis to determine whether adjustments to the valuation allowance are appropriate considering changes in facts or circumstances. As of each reporting date, management considers new evidence, both positive and negative, when determining the future realization of the Company’s deferred tax assets. Given the Company’s current level of pre-tax earnings and forecasted future pre-tax earnings, the Company expects to generate income before taxes in the U.S. in future periods at a level that would fully utilize its U.S. federal NOL carryforwards and the majority of its state NOL carryforwards prior to their expiration.

The Company continues to maintain a valuation allowance of $275 million as of December 31, 2023 against deferred tax assets consisting of state NOL carryforwards and foreign NOL carryforwards in jurisdictions where the Company does not currently believe that the realization of deferred tax assets is more likely than not. As of December 31, 2022, the Company's valuation allowance balance was $224 million.

Considerable judgment is required to determine the tax treatment of a particular item that involves interpretations of complex tax laws. The Company is subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state and foreign jurisdictions, including operations located in Australia and Canada. The Company continues to be under audit for multiple years by taxing authorities in various jurisdictions.

The Company is no longer subject to U.S. federal income tax examinations for years prior to 2020. With few exceptions, state and Canadian income tax examinations are no longer open for years before 2015.

NRG does not intend, nor currently foresee a need, to repatriate funds held at its international operations into the U.S. These funds are deemed to be indefinitely reinvested in its foreign operations and the Company has not changed its assertion with respect to distributions of funds that would require the accrual of U.S. income tax.

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Evaluation of Assets for Impairment

In accordance with ASC 360, Property, Plant, and Equipment ("ASC 360"), the Company evaluates property, plant and equipment and certain intangible assets for impairment whenever indicators of impairment exist. Examples of such indicators or events include:

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

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

•Adverse business climate;

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

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

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

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

For assets to be held and used, if the Company determines that the undiscounted cash flows from the asset are less than the carrying amount of the asset, NRG must estimate fair value to determine the amount of any impairment loss. Assets held-for-sale are reported at the lower of the carrying amount or fair value less the cost to sell. The estimation of fair value, whether in conjunction with an asset to be held and used or with an asset held-for-sale, and the evaluation of asset impairment are, by their nature, subjective. The Company considers quoted market prices in active markets to the extent they are available. In the absence of such information, NRG may consider prices of similar assets, consult with brokers or employ other valuation techniques. The Company will also discount the estimated future cash flows associated with the asset using a single interest rate representative of the risk involved with such an investment or asset. The use of these methods involves the same inherent uncertainty of future cash flows as previously discussed with respect to undiscounted cash flows. Actual future market prices and project costs could vary from those used in NRG's estimates and the impact of such variations could be material.

Annually, during the fourth quarter, the Company revises its views of power and fuel prices including the Company's fundamental view for long-term prices, forecasted generation and operating and capital expenditures, in connection with the preparation of its annual budget. Changes to the Company's views of long-term power and fuel prices impact the Company’s projections of profitability, based on management's estimate of supply and demand within the sub-markets for its operations and the physical and economic characteristics of each of its businesses.

For further discussion, see Item 15 — Note 11, Asset Impairments.

Goodwill and Other Intangible Assets

At December 31, 2023, the Company reported goodwill of $5.1 billion, consisting of $3.5 billion from the acquisition of Vivint in 2023, $1.3 billion from the acquisition of Direct Energy in 2021 and $0.3 billion from other retail acquisitions.

The Company applies ASC 805, Business Combinations ("ASC 805"), and ASC 350, Intangibles-Goodwill and Other ("ASC 350") to account for its goodwill and intangible assets. Under these standards, the Company amortizes all finite-lived intangible assets over their respective estimated weighted-average useful lives, while goodwill has an indefinite life and is not amortized. Goodwill is tested for impairment at least annually, or more frequently whenever an event or change in circumstances occurs that would more likely than not reduce the fair value of a reporting unit below its carrying amount. The Company tests goodwill for impairment at the reporting unit level, which is identified by assessing whether the components of the Company's operating segments constitute businesses for which discrete financial information is available and whether segment management regularly reviews the operating results of those components. The Company performs the annual goodwill impairment assessment as of December 31 or when events or changes in circumstances indicate that the fair value of the reporting unit may be below the carrying amount. The Company may first assess qualitative factors to determine whether it is more likely than not that an impairment has occurred. In the absence of sufficient qualitative factors, the Company performs a quantitative assessment by determining the fair value of the reporting unit and comparing to its book value. If it is determined that the fair value of a reporting unit is below its carrying amount, the Company's goodwill will be impaired at that time.

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Fair value determinations require considerable judgment and are sensitive to changes in underlying assumptions and factors. As a result, there can be no assurance that the estimates and assumptions made for purposes of the annual goodwill impairment test will prove to be accurate predictions of the future.

For further discussion, see Evaluation of Assets for Impairment caption above, and Item 15 — Note 11, Asset Impairments.

Business Combinations

NRG accounts for business acquisitions using the acquisition method of accounting prescribed under ASC 805. Under this method, the Company is required to record on its Consolidated Balance Sheets the estimated fair values of the acquired company’s assets and liabilities assumed at the acquisition date. The excess of the consideration transferred over the fair value of the net identifiable assets acquired and liabilities assumed is recorded as goodwill. Determining fair values of assets acquired and liabilities assumed requires significant estimates and judgments. Fair value is determined based on the estimated price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The acquired assets and assumed liabilities from the Vivint Smart Home acquisition that involved the most subjectivity in determining fair value consisted of customer relationships, developed technology, trade names, acquired debt and derivative instruments. NRG describes in detail its acquisitions in Item 15 — Note 4, Acquisitions and Dispositions, to the Consolidated Financial Statements.

The fair value of the customer relationships, technology and trade names are measured using income-based valuation methodologies, which include certain assumptions such as forecasted future cash flows, customer attrition rates, royalty rates and discount rates. Customer relationships and technology are amortized to depreciation and amortization, ratably based on discounted future cash flows. Trade names are amortized to depreciation and amortization, on a straight line basis.

The acquired Vivint Smart Home debt was measured at fair value using observable market inputs based on interest rates at the acquisition closing date. The difference between the fair value at the acquisition closing date and the principal outstanding is being amortized through interest expense over the remaining term of the debt.

The derivative liabilities in connection with the contractual future payment obligations with the financing providers under Vivint Smart Home’s Consumer Financing Program were measured at fair value at the acquisition closing date using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates. Changes to the fair value are recorded each period through other income, net in the consolidated statement of operations.

Contingencies

NRG 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. Gain contingencies are not recorded until management determines it is certain that the future event will become or does become a reality. Such determinations are subject to interpretations of current facts and circumstances, forecasts of future events, and estimates of the financial impacts of such events. NRG describes in detail its contingencies in Item 15 — Note 23, Commitments and Contingencies, to the Consolidated Financial Statements.

Recent Accounting Developments

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

Item 7A — Quantitative and Qualitative Disclosures About Market Risk

NRG is exposed to several market risks in the Company's normal business activities. Market risk is the potential loss that may result from market changes associated with the Company's retail operations, merchant power generation, or with an existing or forecasted financial or commodity transactions. The types of market risks the Company is exposed to are commodity price risk, credit risk, liquidity risk, interest rate risk and currency exchange risk. In order to manage these risks, the Company uses various fixed-price forward purchase and sales contracts, futures and option contracts traded on NYMEX and other exchanges, and swaps and options traded in the over-the-counter financial markets to:

•Manage and hedge fixed-price purchase and sales commitments;

•Reduce exposure to the volatility of cash market prices, and

•Hedge fuel requirements for the Company's generating facilities.

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Commodity Price Risk

Commodity price risks result from exposures to changes in spot prices, forward prices, volatilities, and correlations between various commodities, such as natural gas, electricity, coal, oil, and emissions credits. NRG manages the commodity price risk of the Company's load servicing obligations and merchant generation operations by entering into various derivative or non-derivative instruments to hedge the variability in future cash flows from forecasted sales and purchases of power and fuel. NRG measures the risk of the Company's portfolio using several analytical methods, including sensitivity tests, scenario tests, stress tests, position reports and VaR. NRG uses a Monte Carlo simulation based VaR model to estimate the potential loss in the fair value of its energy assets and liabilities, which includes generation assets, gas transportation and storage assets, load obligations and bilateral physical and financial transactions, based on historical and forward values for factors such as customer demand, weather, commodity availability and commodity prices. The Company's VaR model is based on a one-day holding period at a 95% confidence interval for the forward 36 months, not including the spot month. The VaR model is not a complete picture of all risks that may affect the Company's results. Certain events such as counterparty defaults, regulatory changes, and extreme weather and prices that deviate significantly from historically observed values are not reflected in the model.

The following table summarizes average, maximum and minimum VaR for NRG's commodity portfolio, calculated using the VaR model for the years ended December 31, 2023 and 2022:

(In millions)	2023		2022
VaR as of December 31,	$	51	$	74
For the year ended December 31,
Average	$	62	$	51
Maximum	82		86
Minimum	41		26

The Company also uses VaR to estimate the potential loss of derivative financial instruments that are subject to mark-to-market accounting. These derivative instruments include transactions that were entered into for both asset management and trading purposes. The VaR for the derivative financial instruments calculated using the diversified VaR model for the entire term of these instruments entered into for both asset management and trading was $185 million as of December 31, 2023, primarily driven by asset-backed transactions.

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. NRG is exposed to counterparty credit risk through various activities including wholesale sales, fuel purchases and retail supply arrangements, and retail customer credit risk through its retail load activities. Counterparty credit risk and retail customer credit risk are discussed below. See Note 6, Accounting for Derivative Instruments and Hedging Activities, to this Form 10-K for discussion regarding credit risk contingent features.

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; (ii) a daily monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties. The Company also has credit protection within various agreements to call on additional collateral support if and when necessary. Cash margin is collected and held at the Company to cover the credit risk of the counterparty until positions settle.

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As of December 31, 2023, counterparty credit exposure, excluding credit exposure from RTOs, ISOs, registered commodity exchanges and certain long-term agreements, was $1.6 billion, of which the Company held collateral (cash and letters of credit) against those positions of $426 million resulting in a net exposure of $1.2 billion. NRG periodically receives collateral from counterparties in excess of their exposure. Collateral amounts shown include such excess while net exposure shown excludes excess collateral received. Approximately 63% of the Company's exposure before collateral is expected to roll off by the end of 2025. The following table highlights the net counterparty credit exposure by industry sector and by counterparty credit quality. Net counterparty credit exposure is defined as the aggregate net asset position for NRG with counterparties where netting is permitted under the enabling agreement and includes all cash flow, mark-to-market, NPNS, and non-derivative transactions. As of December 31, 2023, the aggregate credit exposure is shown net of collateral held, and includes amounts net of receivables or payables.

Category	Net Exposure (a) (b) (% of Total)
Utilities, energy merchants, marketers and other	80	%
Financial institutions	20
Total	100	%

Category	Net Exposure (a) (b) (% of Total)
Investment grade	44	%
Non-Investment grade/Non-Rated	56
Total	100	%

(a)Counterparty credit exposure excludes coal transportation contracts because of the unavailability of market prices

(b)The figures in the tables above exclude potential counterparty credit exposure related to RTOs, ISOs, registered commodity exchanges and certain long-term contracts

The Company has exposure to one wholesale counterparty in excess of 10% of the total net exposure discussed above as of December 31, 2023. Changes in hedge positions and market prices will affect credit exposure and counterparty concentration.

RTOs and ISOs

The Company participates in the organized markets of CAISO, ERCOT, AESO, IESO, ISO-NE, MISO, NYISO and PJM, known as RTOs or ISOs. Trading in the majority of these markets is approved by FERC, whereas in the case of ERCOT, it is approved by the PUCT, and whereas in the case of AESO and IESO, both exist provincially with AESO primarily subject to Alberta Utilities Commission and the IESO subject to the Ontario Energy Board. These ISOs may include credit policies that, under certain circumstances, require that losses arising from the default of one member on spot market transactions be shared by the remaining participants. As a result, the counterparty credit risk to these markets is limited to NRG’s share of the overall market and are excluded from the above exposures.

Exchange Traded Transactions

The Company enters into commodity transactions on registered exchanges, notably ICE, NYMEX and Nodal. These clearinghouses act as the counterparty and transactions are subject to extensive collateral and margining requirements. As a result, these commodity transactions have limited counterparty credit risk.

Long-Term Contracts

Counterparty credit exposure described above excludes credit risk exposure under certain long-term contracts, primarily solar under Renewable PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company values these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. Based on these valuation techniques, as of December 31, 2023, aggregate credit risk exposure managed by NRG to these counterparties was approximately $882 million for the next five years.

Retail Customer Credit Risk

NRG is exposed to retail credit risk through the Company's retail electricity and gas providers as well as through Vivint Smart Home. Retail credit risk results in losses when a customer fails to pay for services rendered. The losses may result from both nonpayment of customer accounts receivable and the loss of in-the-money forward value. The Company manages retail credit risk through the use of established credit policies, which include monitoring of the portfolio and the use of credit mitigation measures such as deposits or prepayment arrangements.

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As of December 31, 2023, the Company's retail customer credit exposure to Home and Business customers was diversified across many customers and various industries, as well as government entities. Current economic conditions may affect the Company's customers' ability to pay bills in a timely manner, which could increase customer delinquencies and may lead to an increase in credit losses. The Company's provision for credit losses resulting from credit risk was $251 million, $11 million and $698 million for the years ended December 31, 2023, 2022 and 2021, respectively. During the year ended December 31, 2022, the provision for credit losses included the Company's loss mitigation efforts recognized as income of $126 million related to Winter Storm Uri. During the year ended December 31, 2021, the provision for credit losses included $596 million of expenses due to the impacts of Winter Storm Uri.

Liquidity Risk

Liquidity risk arises from the general funding needs of the Company's activities and the management of the Company's assets and liabilities. The Company is currently exposed to additional collateral posting if natural gas prices decline, primarily due to the long natural gas equivalent position at various exchanges used to hedge NRG's retail supply load obligations.

Based on a sensitivity analysis for power and gas positions under marginable contracts as of December 31, 2023, a $0.50 per MMBtu decrease in natural gas prices across the term of the marginable contracts would cause an increase in margin collateral posted of approximately $1.5 billion and a 1.00 MMBtu/MWh decrease in heat rates for heat rate positions would result in an increase in margin collateral posted of approximately $350 million. This analysis uses simplified assumptions and is calculated based on portfolio composition and margin-related contract provisions as of December 31, 2023.

Interest Rate Risk

NRG 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 combinations of the variable rate debt and the interest rate derivative instrument. NRG's risk management policies allow the Company to reduce interest rate exposure from variable rate debt obligations. In the first quarter of 2023, the Company entered into $1.0 billion of interest rate swaps through 2027 to hedge the floating rate on the Term Loan acquired with the Vivint Smart Home acquisition. Additionally, in the first quarter of 2023, the Company had entered into interest rate swaps to hedge the floating rate on the Revolving Credit Facility extending through 2024, which was fully terminated in conjunction with the pay down of the Revolving Credit Facility.

As of December 31, 2023, the Company's debt fair value was $10.6 billion and carrying value was $10.8 billion. NRG estimates that a 1% decrease in market interest rates would have increased the fair value of the Company's long-term debt by $602 million.

Currency Exchange Risk

NRG is subject to transactional exchange rate risk from transactions with customers in countries outside of the U.S., primarily within Canada, as well as from intercompany transactions between affiliates. Transactional exchange rate risk arises from the purchase and sale of goods and services in currencies other than the Company's functional currency or the functional currency of an applicable subsidiary. NRG hedges a portion of its forecasted currency transactions with foreign exchange forward contracts. As of December 31, 2023, NRG is exposed to changes in foreign currency primarily associated with the purchase of U.S. dollar denominated natural gas for its Canadian business and entered into foreign exchange contracts with a notional amount of $548 million.

The Company is subject to translation exchange rate risk related to the translation of the financial statements of its foreign operations into U.S. dollars. Costs incurred and sales recorded by subsidiaries operating outside of the U.S. are translated into U.S. dollars using exchange rates effective during the respective period. As a result, the Company is exposed to movements in the exchange rates of various currencies against the U.S. dollar, primarily the Canadian and Australian dollars. A hypothetical 10% appreciation in major currencies relative to the U.S. dollar as of December 31, 2023, would have resulted in a decrease of $36 million to net income within the Consolidated Statement of Operations.

Item 8 — Financial Statements and Supplementary Data

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

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

None.

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Item 9A — Controls and Procedures

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

Under the supervision and with the participation of NRG's management, including its principal executive officer, principal financial officer and principal accounting officer, NRG 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 Annual Report on Form 10-K. Management's report on the Company's internal control over financial reporting and the report of the Company's independent registered public accounting firm are incorporated under the caption "Management's Report on Internal Control over Financial Reporting" and under the caption "Report of Independent Registered Public Accounting Firm" in this Annual Report on Form 10-K for the fiscal year ended December 31, 2023.

Changes in Internal Control over Financial Reporting

During the year ended December 31, 2023, the Company completed its acquisition of Vivint Smart Home, Inc. As part of integration, the Company designed and implemented a control structure over Vivint Smart Home's operations. Other than the Vivint Smart Home acquisition, there were no changes in NRG’s internal control over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred in the fourth quarter of 2023 that materially affected, or are reasonably likely to materially affect, NRG’s internal control over financial reporting.

Inherent Limitations over Internal Controls

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

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

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

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

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

Management's Report on Internal Control over Financial Reporting

The Company's management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Under the supervision and with the participation of the Company's management, including its principal executive officer, principal financial officer and principal accounting officer, the Company conducted an evaluation of the effectiveness of its internal control over financial reporting based on the framework in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on the Company's evaluation under the framework in Internal Control — Integrated Framework (2013), the Company's management concluded that its internal control over financial reporting was effective as of December 31, 2023.

On March 10, 2023, NRG acquired Vivint Smart Home, Inc., and management excluded from its assessment of the effectiveness of the Company's internal control over financial reporting as of December 31, 2023, Vivint Smart Home, Inc.'s internal control over financial reporting associated with total assets (excluding acquired goodwill and intangible assets) of 5% and total revenues of 5% included in the consolidated financial statements of the Company as of and for the year ended December 31, 2023.

The effectiveness of the Company's internal control over financial reporting as of December 31, 2023 has been audited by KPMG LLP, the Company's independent registered public accounting firm, as stated in its report which is included in this Annual Report on Form 10-K.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders

NRG Energy, Inc.:

Opinion on Internal Control Over Financial Reporting

We have audited NRG Energy, Inc. and subsidiaries' (the Company) internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 2023 and 2022, the related consolidated statements of operations, comprehensive (loss)/income, stockholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2023, and the related notes and financial statement schedule II (collectively, the consolidated financial statements), and our report dated February 28, 2024 expressed an unqualified opinion on those consolidated financial statements.

The Company acquired Vivint Smart Home, Inc. during 2023, and management excluded from its assessment of the effectiveness of the Company's internal control over financial reporting as of December 31, 2023, Vivint Smart Home, Inc.'s internal control over financial reporting associated with total assets (excluding acquired goodwill and intangible assets) of 5% and total revenues of 5% included in the consolidated financial statements of the Company as of and for the year ended December 31, 2023. Our audit of internal control over financial reporting of the Company also excluded an evaluation of the internal control over financial reporting of Vivint Smart Home, Inc.

Basis for Opinion

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

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

Definition and Limitations of Internal Control Over Financial Reporting

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

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

/s/ KPMG LLP

Philadelphia, Pennsylvania

February 28, 2024

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Item 9B — Other Information

Director and Officer Trading Arrangements

During the three months ended December 31, 2023, the following directors or officers of the Company adopted or terminated a 'Rule 10b5-1 trading arrangement' or 'non-Rule 10b5-1 trading arrangement,' as each term is defined in Item 408(a) of Regulation S-K, as described in the table below:

Name	Title	Date Adopted	Character of Trading Arrangement	Aggregate Number of Shares of Common Stock to be Purchased or Sold Pursuant to Trading Arrangement(a)	Duration	Date Terminated
Elizabeth Killinger	Executive Vice President	12/15/2023	Rule 10b5-1 Trading Arrangement	65,583 shares to be Sold(b)	3/15/2024-1/31/2025	N/A
Rasesh Patel	Executive Vice President, Smart Home	12/15/2023	Rule 10b5-1 Trading Arrangement	Up to 73,638 shares to be Sold	3/14/2024-11/01/2024	N/A

(a)Potential sales may be subject to certain price limitations set forth in the 10b5-1 plans and therefore actual number of shares sold could vary if certain minimum stock prices are not met

(b)Represents approximate number of shares to be sold based on outstanding awards expected to vest during the period, where any underlying performance share awards are being calculated at target. Actual number of shares to be sold will depend on actual vesting, the number of shares withheld by NRG to satisfy tax withholding obligations and vesting of dividend equivalent rights

Item 9C — Disclosure Regarding Foreign Jurisdictions that Prevent Inspections

Not applicable.

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PART III

Item 10 — Directors, Executive Officers and Corporate Governance

Directors and Executive Officers

Information required by this Item is incorporated by reference to the similarly named section of NRG's Definitive Proxy Statement for its 2024 Annual Meeting of Stockholders.

Code of Ethics

NRG has adopted a code of ethics entitled "NRG Code of Conduct" that applies to directors, officers and employees, including the chief executive officer and senior financial officers of NRG. It may be accessed through the "Governance" section of the Company's website at www.nrg.com. NRG also elects to disclose the information required by Form 8-K, Item 5.05, "Amendments to the Registrant's Code of Ethics, or Waiver of a Provision of the Code of Ethics," through the Company's website, and such information will remain available on this website for at least a 12-month period. A copy of the "NRG Code of Conduct" is available in print to any stockholder who requests it.

Other information required by this Item is incorporated by reference to the similarly named section of NRG's Definitive Proxy Statement for its 2024 Annual Meeting of Stockholders.

Item 11 — Executive Compensation

Information required by this Item is incorporated by reference to the similarly named section of NRG's Definitive Proxy Statement for its 2024 Annual Meeting of Stockholders.

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

Securities Authorized for Issuance under Equity Compensation Plans

Plan Category	(a) Number of Securities to be Issued Upon Exercise of Outstanding Options, Warrants and Rights		(b) Weighted-Average Exercise Price of Outstanding Options, Warrants and Rights		(c) Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (Excluding Securities Reflected in Column (a))
Equity compensation plans approved by security holders	2,997,640	(1)	$	—	14,419,264
Equity compensation plans not approved by security holders	3,970,872	(2)	$	—	12,749,736
Total	6,968,512		$	—	27,169,000	(3)

(1)Consists of shares issuable under the NRG LTIP and the ESPP. On April 27, 2023, NRG stockholders approved an increase of 4,400,000 shares available for issuance under the ESPP. As of December 31, 2023, there were 6,702,125 shares reserved from the Company's treasury shares for the ESPP

(2)Consists of shares issuable under the Vivint LTIP. On March 10, 2023, in connection with the Acquisition, NRG assumed the Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan. While the Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan was previously approved by stockholders of Vivint Smart Home, Inc., the plan is listed as "not approved" because it was assumed as part of the Acquisition and not subject to approval by NRG stockholders. The Company intends to make subsequent grants under the Vivint LTIP. See Note 21, Stock-Based Compensation for a discussion of the Vivint LTIP

(3)Consists of 7,717,139 shares of common stock under the NRG LTIP, 12,749,736 shares of common stock under the Vivint LTIP and 6,702,125 shares of treasury stock reserved for issuance under the ESPP

The NRG LTIP currently provides for grants of restricted stock units, relative performance stock units, deferred stock units and dividend equivalent rights. The Vivint LTIP currently provides for grants of restricted stock units and performance stock units. The Company's directors, officers and employees, as well as other individuals performing services for, or to whom an offer of employment has been extended by the Company, are eligible to receive grants under the LTIPs. The purpose of the LTIPs is to promote the Company's long-term growth and profitability by providing these individuals with incentives to maximize stockholder value and otherwise contribute to the Company's success and to enable the Company to attract, retain and reward the best available persons for positions of responsibility. The Compensation Committee of the Board of Directors administers the LTIPs.

Other information required by this Item is incorporated by reference to the similarly named section of NRG's Definitive Proxy Statement for its 2024 Annual Meeting of Stockholders.

78

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

Information required by this Item is incorporated by reference to the similarly named section of NRG's Definitive Proxy Statement for its 2024 Annual Meeting of Stockholders.

Item 14 — Principal Accounting Fees and Services

Information required by this Item is incorporated by reference to the similarly named section of NRG's Definitive Proxy Statement for its 2024 Annual Meeting of Stockholders.

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PART IV

Item 15 — Exhibits, Financial Statement Schedules

(a)(1) Financial Statements

The following consolidated financial statements of NRG Energy, Inc. and related notes thereto, together with the reports thereon of KPMG LLP, Philadelphia, PA, Auditor Firm ID: 185, are included herein:

Consolidated Statements of Operations — Years ended December 31, 2023, 2022, and 2021

Consolidated Statements of Comprehensive (Loss)/Income — Years ended December 31, 2023, 2022, and 2021

Consolidated Balance Sheets — As of December 31, 2023 and 2022

Consolidated Statements of Cash Flows — Years ended December 31, 2023, 2022, and 2021

Consolidated Statements of Stockholders' Equity — Years ended December 31, 2023, 2022, and 2021

Notes to Consolidated Financial Statements

(a)(2) Financial Statement Schedule

The following Consolidated Financial Statement Schedule of NRG Energy, Inc. is filed as part of Item 15 of this report and should be read in conjunction with the Consolidated Financial Statements.

Schedule II — Valuation and Qualifying Accounts

All other schedules for which provision is made in the applicable accounting regulation of the Securities and Exchange Commission are not required under the related instructions or are inapplicable, and therefore, have been omitted.

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

(b) Exhibits

See Exhibit Index submitted as a separate section of this report.

(c) Not applicable

80

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders

NRG Energy, Inc.:

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of NRG Energy, Inc. and subsidiaries (the Company) as of December 31, 2023 and 2022, the related consolidated statements of operations, comprehensive (loss)/income, stockholders' equity, and cash flows for each of the years in the three-year period ended December 31, 2023, and the related notes and financial statement schedule II (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2023 and 2022, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2023, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 28, 2024 expressed an unqualified opinion on the effectiveness of the Company's internal control over financial reporting.

Basis for Opinion

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

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

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

Evaluation of the sufficiency of audit evidence over revenues

As discussed in Note 3 to the consolidated financial statements, the Company had $28,823 million of revenues. Revenue is derived from various revenue streams in different geographic markets and the Company’s processes and related information technology (IT) systems used to record revenue differ for each of these revenue streams.

We identified the evaluation of the sufficiency of audit evidence over revenues as a critical audit matter which required a high degree of auditor judgment due to the number of revenue streams and IT systems involved in the revenue recognition process. This included determining the revenue streams over which procedures were to be performed and evaluating the nature and extent of evidence obtained over the individual revenue streams as well as revenue in the aggregate. It also included the involvement of IT professionals with specialized skills and knowledge to assist in the performance of certain procedures.

The following are the primary procedures we performed to address this critical audit matter. We, with the assistance of IT professionals, applied auditor judgment to determine the revenue streams over which procedures were performed as well as the nature and extent of such procedures. For certain revenue streams over which procedures were performed,

81

we evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s revenue recognition processes. For certain revenue streams, we involved IT professionals, who assisted in testing certain IT applications used by the Company in its revenue recognition processes. In addition, we assessed recorded revenue for a selection of transactions by comparing the amounts recognized to underlying documentation, including contracts with customers, and for certain revenue streams, we performed a software-assisted data analysis to assess certain relationships among revenue transactions. In addition, we evaluated the sufficiency of audit evidence obtained over revenues by assessing the results of procedures performed, including the appropriateness of such evidence.

Fair value of certain acquired intangible assets

As discussed in Note 4 to the consolidated financial statements, the Company acquired Vivint Smart Home, Inc. on March 10, 2023 for total consideration of $2,623 million. In connection with the business combination, the Company recorded various intangible assets, which included customer relationships and technology intangible assets with an acquisition-date fair value of $1,740 million and $860 million, respectively.

We identified the evaluation of the acquisition-date fair value of the customer relationships and technology intangible assets as a critical audit matter. A high degree of subjective and complex auditor judgment was required to evaluate key assumptions used to value these acquired intangible assets. We performed sensitivity analyses to determine the key assumptions used to value the intangible assets acquired which required challenging auditor judgment. Specifically, key assumptions included the customer attrition for the customer relationships intangible asset and the discount rate for the customer relationships and technology intangible assets. Changes to these assumptions could have had a significant impact on the fair value of such assets. In addition, valuation professionals with specialized skills and knowledge were needed to assist in the evaluation of the discount rate.

The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls related to the Company’s acquisition-date valuation process, including controls related to the selection of the customer attrition used in the customer relationships intangible asset and the discount rate used in the customer relationships and technology intangible assets. We evaluated the customer attrition used by the Company by comparing it to historical attrition experienced by the acquired company and comparable company attrition. We involved valuation professionals with specialized skills and knowledge, who assisted in evaluating the discount rate by assessing the relative risk profile of the customer relationships and technology intangible assets compared to the required rate of return of all acquired assets in the business combination.

/s/ KPMG LLP

We have served as the Company's auditor since 2004.

Philadelphia, Pennsylvania

February 28, 2024

82

NRG ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

	For the Year Ended December 31,
(In millions, except per share amounts)	2023		2022		2021
Revenue
Revenue	$	28,823	$	31,543	$	26,989
Operating Costs and Expenses
Cost of operations (excluding depreciation and amortization shown below)	26,526		27,446		20,482
Depreciation and amortization	1,127		634		785
Impairment losses	26		206		544
Selling, general and administrative costs	1,968		1,228		1,293
Provision for credit losses	251		11		698
Acquisition-related transaction and integration costs	119		52		93
Total operating costs and expenses	30,017		29,577		23,895
Gain on sale of assets	1,578		52		247
Operating Income	384		2,018		3,341
Other Income/(Expense)
Equity in earnings of unconsolidated affiliates	16		6		17
Impairment losses on investments	(102)		—		—
Other income, net	47		56		63
Gain/(Loss) on debt extinguishment	109		—		(77)
Interest expense	(667)		(417)		(485)
Total other expense	(597)		(355)		(482)
(Loss)/Income Before Income Taxes	(213)		1,663		2,859
Income tax (benefit)/expense	(11)		442		672
Net (Loss)/Income	(202)		1,221		2,187
Less: Cumulative dividends attributable to Series A Preferred Stock	54		—		—
Net (Loss)/Income Available for Common Stockholders	$	(256)	$	1,221	$	2,187
(Loss)/Income Per Share
Weighted average number of common shares outstanding — basic and diluted	228		236		245
(Loss)/Income per Weighted Average Common Share — Basic and Diluted	$	(1.12)	$	5.17	$	8.93

See notes to Consolidated Financial Statements

83

NRG ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS)/INCOME

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Net (Loss)/Income	$	(202)	$	1,221	$	2,187
Other Comprehensive Income/(Loss), net of tax
Foreign currency translation adjustments	9		(35)		(5)
Defined benefit plans	30		(16)		85
Other comprehensive income/(loss)	39		(51)		80
Comprehensive (Loss)/Income	$	(163)	$	1,170	$	2,267

See notes to Consolidated Financial Statements

84

NRG ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

	As of December 31,
(In millions)	2023		2022
ASSETS
Current Assets
Cash and cash equivalents	$	541	$	430
Funds deposited by counterparties	84		1,708
Restricted cash	24		40
Accounts receivable, net	3,542		4,773
Inventory	607		751
Derivative instruments	3,862		7,886
Cash collateral paid in support of energy risk management activities	441		260
Prepayments and other current assets	626		383
Total current assets	9,727		16,231
Property, plant and equipment, net	1,763		1,692
Other Assets
Equity investments in affiliates	42		133
Operating lease right-of-use assets, net	179		225
Goodwill	5,079		1,650
Customer relationships, net	2,164		943
Other intangible assets, net	1,763		1,189
Nuclear decommissioning trust fund	—		838
Derivative instruments	2,293		4,108
Deferred income taxes	2,251		1,881
Other non-current assets	777		256
Total other assets	14,548		11,223
Total Assets	$	26,038	$	29,146

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NRG ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (Continued)

	As of December 31,
(In millions, except share data)	2023		2022
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Current portion of long-term debt and finance leases	$	620	$	63
Current portion of operating lease liabilities	90		83
Accounts payable	2,325		3,643
Derivative instruments	4,019		6,195
Cash collateral received in support of energy risk management activities	84		1,708
Deferred revenue current	720		176
Accrued expenses and other current liabilities	1,642		1,114
Total current liabilities	9,500		12,982
Other Liabilities
Long-term debt and finance leases	10,133		7,976
Non-current operating lease liabilities	128		180
Nuclear decommissioning reserve	—		340
Nuclear decommissioning trust liability	—		477
Derivative instruments	1,488		2,246
Deferred income taxes	22		134
Deferred revenue non-current	914		10
Other non-current liabilities	947		973
Total other liabilities	13,632		12,336
Total Liabilities	23,132		25,318
Commitments and Contingencies
Stockholders' Equity
Preferred stock; 10,000,000 shares authorized; 650,000 Series A shares issued and outstanding at December 31, 2023 (aggregate liquidation preference $650); 0 shares issued and outstanding at December 31, 2022	650		—
Common stock; $0.01 par value; 500,000,000 shares authorized; 267,330,470 and 423,897,001 shares issued; and 208,130,950 and 229,561,030 shares outstanding at December 31, 2023 and 2022, respectively	3		4
Additional paid-in capital	3,416		8,457
Retained earnings	820		1,408
Treasury stock, at cost; 59,199,520 and 194,335,971 shares at December 31, 2023 and 2022, respectively	(1,892)		(5,864)
Accumulated other comprehensive loss	(91)		(177)
Total Stockholders' Equity	2,906		3,828
Total Liabilities and Stockholders' Equity	$	26,038	$	29,146

See notes to Consolidated Financial Statements

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NRG ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Cash Flows from Operating Activities
Net (loss)/income	$	(202)	$	1,221	$	2,187
Adjustments to reconcile net income to net cash provided by operating activities:
Equity in and distributions from (earnings)/losses of unconsolidated affiliates	(6)		7		20
Depreciation and amortization	1,127		634		785
Accretion of asset retirement obligations	27		55		30
Provision for credit losses	251		11		698
Amortization of nuclear fuel	47		54		51
Amortization of financing costs and debt discounts	52		23		39
(Gain)/Loss on debt extinguishment	(109)		—		77
Amortization of in-the-money contracts and emissions allowances	137		158		106
Amortization of unearned equity compensation	101		28		21
Net gain on sale of assets and disposal of assets	(1,559)		(102)		(261)
Impairment losses	128		206		544
Changes in derivative instruments	2,455		(3,221)		(3,626)
Changes in deferred income taxes and liability for uncertain tax benefits	(92)		382		604
Changes in collateral deposits in support of risk management activities	(1,806)		896		797
Changes in nuclear decommissioning trust liability	—		9		40
Uplift securitization proceeds received/(receivable) from ERCOT	—		689		(689)
Cash (used)/provided by changes in other working capital, net of acquisition and disposition effects:
Accounts receivable - trade	840		(1,560)		(1,232)
Inventory	189		(252)		(61)
Prepayments and other current assets	(233)		17		31
Accounts payable	(1,455)		1,295		476
Accrued expenses and other current liabilities	360		(29)		(55)
Other assets and liabilities	(473)		(161)		(89)
Cash (used)/provided by operating activities	$	(221)	$	360	$	493
Cash Flows from Investing Activities
Payments for acquisitions of businesses and assets, net of cash acquired	$	(2,523)	$	(62)	$	(3,559)
Capital expenditures	(598)		(367)		(269)
Net purchases of emissions allowances	(24)		(6)		—
Investments in nuclear decommissioning trust fund securities	(367)		(454)		(751)
Proceeds from sales of nuclear decommissioning trust fund securities	355		448		710
Proceeds from sale of assets, net of cash disposed	2,007		109		830
Proceeds from insurance recoveries for property, plant and equipment, net	240		—		—
Cash used by investing activities	$	(910)	$	(332)	$	(3,039)

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	For the Year Ended December 31,
(In millions)	2023		2022		2021
Cash Flows from Financing Activities
Proceeds from issuance of preferred stock, net of fees	$	635	$	—	$	—
Net receipts from settlement of acquired derivatives that include financing elements	342		1,995		938
Payments for share repurchase activity(a)	(1,172)		(606)		(48)
Payments of dividends to preferred and common stockholders	(381)		(332)		(319)
Proceeds from issuance of long-term debt	731		—		1,100
Payments for short and long-term debt	(523)		(5)		(1,861)
Payments for debt extinguishment costs	—		—		(65)
Payments of debt issuance costs	(32)		(9)		(18)
Proceeds from issuance of common stock	—		—		1
Proceeds from credit facilities	3,020		—		1,415
Repayments to credit facilities	(3,020)		—		(1,415)
Cash (used)/provided by financing activities	$	(400)	$	1,043	$	(272)
Effect of exchange rate changes on cash and cash equivalents	2		(3)		(2)
Net (Decrease)/Increase in Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash	(1,529)		1,068		(2,820)
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at Beginning of Period	2,178		1,110		3,930
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at End of Period	$	649	$	2,178	$	1,110

(a)Includes $(22) million, $(6) million and $(9) million of equivalent shares purchased in lieu of tax withholdings on equity compensation issuances for the years ended December 31, 2023, 2022 and 2021, respectively

For further discussion of supplemental cash flow information see Note 26, Cash Flow Information

See notes to Consolidated Financial Statements

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NRG ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In millions)	Preferred Stock		Common Stock		Additional Paid-In Capital		(Accumulated Deficit)/Retained Earnings		Treasury Stock		Accumulated Other Comprehensive Loss		Total Stock-holders' Equity
Balance at December 31, 2020	$	—	$	4	$	8,517	$	(1,403)	$	(5,232)	$	(206)	$	1,680
Net income							2,187						2,187
Other comprehensive income											80		80
Shares reissuance for ESPP					1				3				4
Share repurchases									(44)				(44)
Equity-based awards activity, net(a)					12								12
Issuance of common stock					1								1
Common stock dividends and dividend equivalents declared(b)							(320)						(320)
Balance at December 31, 2021	$	—	$	4	$	8,531	$	464	$	(5,273)	$	(126)	$	3,600
Net income							1,221						1,221
Other comprehensive loss											(51)		(51)
Shares reissuance for ESPP					2				4				6
Share repurchases									(595)				(595)
Equity-based awards activity, net(a)					24								24
Common stock dividends and dividend equivalents declared(b)							(334)						(334)
Adoption of ASU 2020-06					$	(100)	57						(43)
Balance at December 31, 2022	$	—	$	4	$	8,457	$	1,408	$	(5,864)	$	(177)	$	3,828
Net loss							(202)						(202)
Issuance of Series A Preferred Stock	650				(15)								635
Other comprehensive income											39		39
Shares reissuance for ESPP					2				6				8
Share repurchases(c)					(117)				(1,043)				(1,160)
Retirement of treasury stock			(1)		(5,008)				5,009				—
Equity-based awards activity, net(a)					97								97
Common stock dividends and dividend equivalents declared(b)							(352)						(352)
Series A Preferred Stock dividends(d)							(34)						(34)
Sale of the 44% equity interest in STP											47		47
Balance at December 31, 2023	$	650	$	3	$	3,416	$	820	$	(1,892)	$	(91)	$	2,906

(a)Includes $(22) million, $(6) million and $(9) million of equivalent shares purchased in lieu of tax withholding on equity compensation issuances for the years ended December 31, 2023, 2022 and 2021, respectively

(b)Dividends per common share were $1.51, $1.40 and $1.30 for each of the years ended December 31, 2023, 2022 and 2021, respectively

(c)Includes excise tax accrued of $10 million as of December 31, 2023

(d)Dividend per Series A Preferred Stock was $52.96

See notes to Consolidated Financial Statements

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NRG ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1 — Nature of Business

General

NRG Energy, Inc., or NRG or the Company, sits at the intersection of energy and home services. NRG is a leading energy and home services company fueled by market-leading brands, proprietary technologies, and complementary sales channels. Across the United States and Canada, NRG delivers innovative, sustainable solutions, predominately under the brand names such as NRG, Reliant, Direct Energy, Green Mountain Energy and Vivint, while also advocating for competitive energy markets and customer choice. The Company has a customer base that includes approximately 8 million residential consumers in addition to commercial, industrial, and wholesale customers, supported by approximately 13 GW of generation.

The Company's business is segmented as follows:

•Texas, which includes all activity related to customer, plant and market operations in Texas, other than Cottonwood;

•East, which includes all activity related to customer, plant and market operations in the East;

•West/Services/Other, which includes the following assets and activities: (i) all activity related to customer, plant and market operations in the West and Canada, (ii) the Services businesses (iii) activity related to the Cottonwood facility and other investments;

•Vivint Smart Home; and

•Corporate activities.

Note 2 — Summary of Significant Accounting Policies

Basis of Presentation and Principles of Consolidation

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

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

The Company identified an error in the previously issued consolidated financial statements for the year ended December 31, 2021 related to the presentation of cash flows associated with certain borrowings and repayments related to the Revolving Credit Facility. The statement of cash flows for the year ended December 31, 2021 has been adjusted to present on a gross basis the borrowings from the Revolving Credit Facility of $1.4 billion and the related repayments of $1.4 billion. The change had no impact to the total cash used by financing activities for the year ended December 31, 2021. We evaluated the materiality of this error both qualitatively and quantitatively and have concluded it is immaterial to the impacted period.

Winter Storm Uri Uplift Securitization Proceeds

The Texas Legislature passed HB 4492 in May 2021 for ERCOT to mitigate exceptionally high price adders and ancillary service costs incurred by LSEs during Winter Storm Uri. HB 4492 authorized ERCOT to obtain $2.1 billion of financing to distribute to LSEs that were charged and paid to ERCOT those highly priced ancillary service and ORDPA during Winter Storm Uri.

In December 2021, ERCOT filed with the PUCT a calculation of each LSE’s share of proceeds based on the settlement methodology. The Company accounted for the proceeds by analogy to the contribution model within ASC 958-605, Not-for-Profit Entities- Revenue Recognition and the grant model within IAS 20, Accounting for Government Grants and Disclosure of Government Assistance, as a reduction to expenses in the consolidated statements of operations in the 2021 annual period for which the proceeds were intended to compensate. The Company received proceeds of $689 million from ERCOT in June 2022.

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Credit Losses

In accordance with ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, or ASU No. 2016-13, retail trade receivables are reported on the balance sheet net of the allowance for credit losses within accounts receivables, net. Long-term receivables are recorded net in other non-current assets on the consolidated balance sheet. The Company accrues an allowance for current expected credit losses based on (i) estimates of uncollectible revenues by analyzing accounts receivable aging and current and reasonable forecasts of expected economic factors including, but not limited to, unemployment rates and weather-related events, (ii) historical collections and delinquencies, and (iii) counterparty credit ratings for commercial and industrial customers. The Company writes off customer contract receivable balances against the allowance for credit losses when it is determined a receivable is uncollectible.

The following table represents the activity in the allowance for credit losses for the years ended December 31, 2023, 2022, and 2021:

	Year Ended December 31,
(In millions)	2023		2022		2021
Beginning balance	$	133	$	683	$	67
Acquired balance from Vivint Smart Home	22		—		—
Acquired balance from Direct Energy	—		—		112
Provision for credit losses(a)	251		11		698
Write-offs	(313)		(593)		(224)
Recoveries collected	39		32		30
Other	13		—		—
Ending balance(a)	$	145	$	133	$	683

(a)Includes bilateral finance hedging risk of $(70) million and $403 million accounted for under ASC 815 for the years ended December 31, 2022 and December 31, 2021, respectively

During the year ended December 31, 2022, the provision for credit losses included the Company's loss mitigation efforts recognized as income of $126 million related to Winter Storm Uri. During the year ended December 31, 2021, the provision for credit losses included $596 million of expense due to the impacts of Winter Storm Uri. The increase in write-offs for the periods ended December 31, 2022 and 2021 were primarily due to the resolution of credit losses that occurred during Winter Storm Uri.

Cash and Cash Equivalents

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase.

Funds Deposited by Counterparties

Funds deposited by counterparties consist of cash held by the Company as a result of collateral posting obligations from its counterparties related to NRG's hedging program. The decrease in funds deposited by counterparties is driven by the significant decrease in forward positions as a result of decreases in natural gas and power prices compared to December 31, 2022. Though some amounts are segregated into separate accounts, not all funds are contractually restricted. Based on the Company's intention, these funds are not available for the payment of general corporate obligations; however, they are available for liquidity management. Depending on market fluctuations and the settlement of the underlying contracts, the Company will refund this collateral to the hedge counterparties pursuant to the terms and conditions of the underlying trades. Since collateral requirements fluctuate daily and the Company cannot predict if any collateral will be held for more than twelve months, the funds deposited by counterparties are classified as a current asset on the Company's balance sheet, with an offsetting liability for this cash collateral received within current liabilities.

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Restricted Cash

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

	Year Ended December 31,
(In millions)	2023		2022		2021
Cash and cash equivalents	$	541	$	430	$	250
Funds deposited by counterparties	84		1,708		845
Restricted cash	24		40		15
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	649	$	2,178	$	1,110

Restricted cash consists primarily of funds held to satisfy the requirements of certain financing agreements and funds held within the Company's projects that are restricted in their use.

Inventory

Inventory is valued at the lower of weighted average cost or market, and consists principally of natural gas, fuel oil, coal, spare parts and finished goods. The Company removes natural gas inventory as goods are delivered to customers and as they are used in the production of electricity or steam. The Company removes fuel oil and coal inventories as they are used in the production of electricity. The Company removes spare parts inventories when they are used for repairs, maintenance or capital projects. The Company expects to recover the natural gas, fuel oil, coal and spare parts costs in the ordinary course of business. Inventory is valued at the lower of cost or net realizable value with cost being determined on a first in first out basis for finished goods and weighted average cost method for all other inventories. The Company removes finished goods inventories as they are sold to customers. Inventories sold to customers as part of a smart home system are generally capitalized as contract costs. Sales of inventory are classified as an operating activity in the consolidated statements of cash flows.

Property, Plant and Equipment

Property, plant and equipment are stated at cost or, in the case of business acquisitions, fair value; however, impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying values may not be recoverable. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation, other than nuclear fuel, is computed using the straight-line method, while nuclear fuel was amortized based on units of production over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations. For further discussion, see Note 9, Property, Plant and Equipment.

Business Interruption Insurance

The Company carries insurance policies to cover insurable risks including, but not limited to, business interruption. As a result of damage at the Limestone 1 and W.A. Parish 8 units, the Company recorded business interruption insurance settlements of $7 million and $81 million during the year ended December 31, 2023 and December 31, 2022, respectively. Business interruption insurance is recorded to cost of operations in the consolidated statements of operations and cash provided by operating activities in the consolidated statement of cash flows.

Asset Impairments

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

Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures, or ASC 323, which requires that a loss in value of an investment that is an other-than-temporary decline should be recognized. The Company identifies and measures losses in the value of equity method investments based upon a comparison of fair value to carrying value. For further discussion of these matters, refer to Note 11, Asset Impairments.

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Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis that approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt, or as an asset if the issuance costs relate to revolving debt agreements or certain other financing arrangements.

Intangible Assets

Intangible assets represent contractual rights held by the Company. The Company recognizes specifically identifiable intangible assets including emissions allowances, customer and supply contracts, customer relationships, marketing partnerships, technologies, trade names and fuel contracts when specific rights and contracts are acquired. These intangible assets are amortized based on expected volumes, expected delivery, expected discounted future net cash flows, straight line or units of production basis. As of December 31, 2023 and 2022, the Company had accumulated amortization related to its intangible assets of $3.0 billion and $2.1 billion, respectively.

Emission allowances held-for-sale, which are included in other non-current assets on the Company's consolidated balance sheet, are not amortized; they are carried at the lower of cost or fair value and reviewed for impairment in accordance with ASC 360.

For further discussion, see Note 12, Goodwill and Other Intangibles.

Goodwill

In accordance with ASC 350, Intangibles-Goodwill and Other, or ASC 350, the Company recognizes goodwill for the excess cost of an acquired entity over the net value assigned to assets acquired and liabilities assumed. NRG performs goodwill impairment tests annually, during the fourth quarter, and when events or changes in circumstances indicate that the carrying value may not be recoverable.

The Company may first assesses qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The more-likely-than-not threshold is defined as having a likelihood of more than 50 percent. If it is not more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, there is no goodwill impairment.

In the absence of sufficient qualitative factors indicating that it is more-likely-than-not that no impairment occurred, the Company performs a quantitative assessment by determining the fair value of the reporting unit and comparing the fair value to its book value. If the fair value of the reporting unit exceeds its book value, goodwill of the reporting unit is not considered impaired. If the book value exceeds fair value, the Company recognizes an impairment loss equal to the difference between book value and fair value.

For further discussion of goodwill impairment losses recognized refer to Note 11, Asset Impairments.

Capitalized Contract Costs

Capitalized contract costs represent the costs directly related and incremental to the origination of new contracts, modification of existing contracts or to the fulfillment of the related subscriber contracts. These costs include installed products, commissions, other compensation and the cost of installation of new or upgraded customer contracts. The Company calculates amortization by accumulating all deferred contract costs into separate portfolios based on the initial month of service and amortizes those deferred contract costs on a straight-line basis over the expected period of benefit, consistent with the pattern in which the Company provides services to its customers. The expected period of benefit for customers is approximately five years. The Company updates its estimate of the expected period of benefit periodically and whenever events or circumstances indicate that the expected period of benefit could change significantly. Such changes, if any, are accounted for prospectively as a change in estimate. Amortization of capitalized contract costs related to fulfillment are included in cost of operations and amortization of capitalized contract costs related to customer acquisition are included in selling, general and administrative costs in the consolidated statements of operations. Contract costs not directly related and incremental to the origination of new contracts, modification of existing contracts or to the fulfillment of the related subscriber contracts are expensed as incurred.

Income Taxes

The Company accounts for income taxes using the liability method in accordance with ASC 740, Income Taxes, or ASC 740, which requires that the Company use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences.

93

The Company has two categories of income tax expense or benefit — current and deferred, as follows:

•Current income tax expense or benefit consists solely of current taxes payable less applicable tax credits, and

•Deferred income tax expense or benefit is the change in the net deferred income tax asset or liability, excluding amounts charged or credited to accumulated other comprehensive income

The Company reports some of its revenues and expenses differently for financial statement purposes than for income tax return purposes, resulting in temporary and permanent differences between the Company's financial statements and income tax returns. The tax effects of such temporary differences are recorded as either deferred income tax assets or deferred income tax liabilities in the Company's consolidated balance sheets. The Company measures its deferred income tax assets and deferred income tax liabilities using income tax rates that are expected to be in effect when the deferred tax is realized.

The Company accounts for uncertain tax positions in accordance with ASC 740, which applies to all tax positions related to income taxes. Under ASC 740, tax benefits are recognized when it is more-likely-than-not that a tax position will be sustained upon examination by the authorities. The benefit recognized from a position is the amount of benefit that has surpassed the more-likely-than-not threshold, as it is more than 50% likely to be realized upon settlement. The Company recognizes interest and penalties accrued related to uncertain tax benefits as a component of income tax expense.

In accordance with ASC 740 and as discussed further in Note 20, Income Taxes, changes to existing net deferred tax assets or valuation allowances or changes to uncertain tax benefits, are recorded to income tax (benefit)/expense.

Contract and Emission Credit Amortization

Assets and liabilities recognized through acquisitions related to the purchase and sale of energy and energy-related products in future periods for which the fair value has been determined to be significantly less or more than market are amortized to revenues or cost of operations over the term of each underlying contract based on actual generation and/or contracted volumes.

Emission credits represent the right to emit a specified amount of certain pollutants, including sulfur dioxide, nitrogen oxides and carbon dioxide, over a compliance period. Emission credits held for use are amortized to cost of operations based on the weighted average cost of the allowances held.

Gross Receipts and Sales Taxes

In connection with its retail sales, the Company records gross receipts taxes on a gross basis in revenues and cost of operations in its consolidated statements of operations. During the years ended December 31, 2023, 2022, and 2021, the Company's revenues and cost of operations included gross receipts taxes of $212 million, $218 million, and $184 million, respectively. Additionally, the Company records sales taxes collected from its taxable retail customers and remitted to the various governmental entities on a net basis; thus, there is no impact on the Company's consolidated statement of operations.

Cost of Operations

Cost of operations includes cost of fuel, purchased energy and other costs of sales, mark-to-market for economic hedging activities, contract and emission credit amortization, operations and maintenance, and other cost of operations.

Cost of Fuel, Purchased Energy and Other Cost of Sales

Cost of fuel is primarily the costs associated with procurement, transportation and storage of natural gas, nuclear fuel, oil and coal to operate the generation portfolio, which is expensed as the fuel is consumed. Purchased energy primarily relates to purchases to supply the Company's customer base, which includes spot market purchases, as well as contracts of various quantities and durations, including Renewable PPAs with third-party developers, which are primarily accounted for as NPNS (see further discussion in Derivative Instruments below). Other cost of sales primarily consists of TDSP expenses.

The cost of fuel is based on actual and estimated fuel usage for the applicable reporting period. The cost to deliver energy and related services to customers is based on actual and estimated supply volumes for the applicable reporting period. A portion of the cost of energy, $240 million, $202 million, and $189 million as of December 31, 2023, 2022, and 2021, respectively, was accrued and consisted of estimated transmission and distribution charges not yet billed by the transmission and distribution utilities.

In estimating supply volumes, the Company considers the effects of historical customer volumes, weather factors and usage by customer class. Transmission and distribution delivery fees are estimated using the same method used for electricity sales and services to retail customers. In addition, ISO fees are estimated based on historical trends, estimated supply volumes and initial ISO settlements. Volume estimates are then multiplied by the supply rate and recorded as cost of operations in the applicable reporting period.

94

Vivint Smart Home Flex Pay

Under the Flex Pay plan (“Flex Pay”), offered by Vivint Smart Home, subscribers pay separately for smart home products and services (smart home and security). The subscriber has the ability to pay for Vivint Smart Home products in the following three ways: (i) qualified subscribers may finance the purchase through third-party financing providers ("Consumer Financing Program" or “CFP”), (ii) Vivint Smart Home generally offers a limited number of subscribers not eligible for the CFP, but who qualify under Vivint Smart Home underwriting criteria, the option to enter into a retail installment contract directly with Vivint Smart Home or (iii) subscribers may conduct purchases by check, automatic clearing house payments, credit or debit card or by obtaining short term financing (generally no more than six-month installment terms) through Vivint Smart Home.

Although subscribers pay separately for products and services under Flex Pay, the Company has determined that the sale of products and services are one single performance obligation resulting in deferred revenue for the gross amount of products sold. For products financed through the CFP, gross deferred revenues are reduced by (i) any fees the third-party financing provider (“Financing Provider”) is contractually entitled to receive at the time of loan origination, and (ii) the present value of expected future payments due to the Financing Providers. Loans are issued on either an installment or revolving basis with repayment terms ranging from 6 to 60 months.

For certain Financing Provider loans:

•Vivint Smart Home pays a monthly fee based on either the average daily outstanding balance of the installment loans, or the number of outstanding loans.

•Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees.

•Vivint Smart Home also shares liability for credit losses, with Vivint Smart Home being responsible for between 2.6% and 100% of lost principal balances.

Due to the nature of these provisions, the Company records a derivative liability ("CFP Derivative") at its fair value when the Financing Provider originates loans to subscribers, which reduces the amount of estimated revenue recognized on the provision of the services. The derivative liability is reduced as payments are made by Vivint Smart Home to the Financing Provider. Subsequent changes to the fair value of the derivative liability are realized through other income, net in the consolidated statements of operations. For further discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities.

Derivative Instruments

The Company accounts for derivative instruments under ASC 815, which requires the Company to record all derivatives on the balance sheet at fair value and changes in fair value in earnings, unless they qualify for the NPNS exception. The Company's primary derivative instruments are power and natural gas purchase or sales contracts, fuels purchase contracts, the CFP and other energy related commodities used to mitigate variability in earnings due to fluctuation in market prices. In order to mitigate interest rate risk associated with the issuance of the Company's variable rate debt, NRG enters into interest rate swap agreements. In addition, in order to mitigate foreign exchange risk associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements.

As of December 31, 2023 and 2022 the Company did not have derivative instruments that were designated as cash flow or fair value hedges.

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

NRG's trading activities are subject to limits in accordance with the Company's Risk Management Policy. These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative instruments are recognized in earnings.

Mark-to-Market for Economic Hedging Activities

NRG enters into derivative instruments to manage price and delivery risk, optimize physical and contractual assets in the portfolio and manage working capital requirements. The mark-to-market for economic hedging activities are recognized to revenues or cost of operations during the reporting period.

Operations and Maintenance and Other Cost of Operations

Operations and maintenance costs include major and other routine preventative (planned outage) and corrective (forced outage) maintenance activities to ensure the safe and reliable operation of the Company's generation portfolio in compliance

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with all local, state and federal requirements. Operations and maintenance costs are also costs associated with retaining and maintaining the Company's customer base, such as call center support, portfolio maintenance and data analytics. Other cost of operations primarily includes gross receipts taxes, insurance, property taxes and asset retirement obligation expense.

Foreign Currency Translation and Transaction Gains and Losses

The local currencies are generally the functional currency of NRG's foreign operations. Foreign currency denominated assets and liabilities are translated at end-of-period rates of exchange. Revenues, expenses, and cash flows are translated at the weighted-average rates of exchange for the period. The resulting currency translation adjustments are not included in the Company's consolidated statements of operations for the period, but are accumulated and reported as a separate component of stockholders' equity until sale or complete or substantially complete liquidation of the net investment in the foreign entity takes place. Foreign currency transaction gains or losses are reported within other income, net in the Company's consolidated statements of operations. For the years ended December 31, 2023, 2022 and 2021, amounts recognized as foreign currency transaction gains/(losses) were immaterial. The Company's cumulative translation adjustment balances as of December 31, 2023, 2022, and 2021 were $(43) million, $(55) million, and $(8) million, respectively.

Concentrations of Credit Risk

Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of trust funds, accounts receivable, notes receivable, derivatives and investments in debt securities. Trust funds are held in accounts managed by experienced investment advisors. Certain accounts receivable, notes receivable, and derivative instruments are concentrated within entities engaged in the energy industry. These industry concentrations may impact the Company's overall exposure to credit risk, either positively or negatively, in that the customers may be similarly affected by changes in economic, industry or other conditions. Receivables and other contractual arrangements are subject to collateral requirements under the terms of enabling agreements. However, the Company believes that the credit risk posed by industry concentration is offset by the diversification and creditworthiness of its customer base. See Note 5, Fair Value of Financial Instruments, for a further discussion of derivative concentrations.

Asset Retirement Obligations

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

Upon initial recognition of a liability for an ARO, the Company capitalizes the asset retirement cost by increasing the carrying amount of the related long-lived asset by the same amount. Over time, the liability is accreted to its future value, while the capitalized cost is depreciated over the useful life of the related asset. See Note 14, Asset Retirement Obligations, for a further discussion of AROs.

Pensions and Other Postretirement Benefits

The Company offers pension benefits through a defined benefit pension plan. In addition, the Company provides postretirement health and welfare benefits for certain groups of employees. The Company accounts for pension and other postretirement benefits in accordance with ASC 715, Compensation — Retirement Benefits, or ASC 715. The Company recognizes the funded status of the Company's defined benefit plans in the statement of financial position and records an offset for gains and losses as well as all prior service costs that have not been included as part of the Company's net periodic benefit cost to other comprehensive income. The determination of the Company's obligation and expenses for pension benefits is dependent on the selection of certain assumptions. These assumptions determined by management include the discount rate, the expected rate of return on plan assets and the rate of future compensation increases. The Company's actuarial consultants assist in determining assumptions for such items as retirement age. The assumptions used may differ materially from actual results, which may result in a significant impact to the amount of pension obligation or expense recorded by the Company.

The Company measures the fair value of its pension assets in accordance with ASC 820, Fair Value Measurements and Disclosures, or ASC 820. For further discussion, see Note 15, Benefit Plans and Other Postretirement Benefits.

Stock-Based Compensation

The Company accounts for its stock-based compensation in accordance with ASC 718, Compensation — Stock Compensation, or ASC 718. The fair value of the Company's performance stock units is estimated on the date of grant using a Monte Carlo valuation model. NRG uses the Company's common stock price on the date of grant as the fair value of the Company's deferred stock units. Forfeiture rates are estimated based on an analysis of the Company's historical forfeitures, employment turnover, and expected future behavior. The Company recognizes compensation expense for both graded and cliff

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vesting awards on a straight-line basis over the requisite service period for the entire award. For further discussion, see Note 21, Stock-Based Compensation.

Investments Accounted for by the Equity Method

The Company has investments in various domestic energy projects, as well as one Australian project. The equity method of accounting is applied to such investments in affiliates, which include joint ventures and partnerships, because the ownership structure prevents the Company from exercising a controlling influence over the operating and financial policies of the projects. Under this method, equity in pre-tax income or losses of domestic partnerships and, generally, in the net income or losses of its Australian project, are reflected as equity in earnings of unconsolidated affiliates. Distributions from equity method investments that represent earnings on the Company's investment are included within cash flows from operating activities and distributions from equity method investments that represent a return of the Company's investment are included within cash flows from investing activities. For further discussion, see Note 17, Investments Accounted for by the Equity Method and Variable Interest Entities.

Sale-Leaseback Arrangements

NRG is party to sale-leaseback arrangements that provide for the sale of certain assets to a third-party and simultaneously leases back the same asset to the Company. If the seller-lessee transfers control of the underlying assets to the buyer-lessor, the arrangement is accounted for under ASC 842-40, Sale-Leaseback Transactions. These arrangements are classified as operating leases on the Company's consolidated balance sheets.

Marketing and Advertising Costs

The Company expenses its marketing and advertising costs as incurred and includes them within selling, general and administrative costs. The costs of tangible assets used in advertising campaigns are recorded as fixed assets or deferred advertising costs and amortized as advertising costs over the shorter of the useful life of the asset or the advertising campaign. The Company has several long-term sponsorship arrangements. Payments related to these arrangements are deferred and expensed over the term of the arrangement. Advertising expenses for the years ended December 31, 2023, 2022, and 2021 were $185 million, $82 million, and $109 million, respectively.

Business Combinations

The Company accounts for its business combinations in accordance with ASC 805, Business Combinations, or ASC 805, which requires an acquirer to recognize and measure in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at fair value at the acquisition date. The Company also recognizes and measures the goodwill acquired or a gain from a bargain purchase in the business combination. In addition, transaction costs are expensed as incurred.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.

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

Reclassifications

Certain prior period amounts have been reclassified for comparative purposes. The reclassifications did not affect results from operations, net assets or cash flows.

Recent Accounting Developments - Guidance Adopted in 2023

ASU 2021-08 — In October 2021, the FASB issued ASU No. 2021-08, Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers, or ASU 2021-08, which requires that an entity recognize and measure contract assets and contract liabilities acquired in a business combination as if it had originated the contracts in accordance with ASC 606, Revenue from Contracts with Customers. As a result, an acquirer should recognize and measuring the acquired contract assets and contract liabilities consistently with how they were recognized and measured in the

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acquiree’s financial statements. The amendments per ASU 2021-08 apply only to contract assets and contract liabilities from contracts with customers, as defined in Topic 606, such as refund liabilities and upfront payments to customers. Assets and liabilities under related Topics, such as deferred costs under Subtopic 340-40, Other Assets and Deferred Costs — Contracts with Customers, are not within the scope of amendments per ASU 2021-08. The Company adopted ASU 2021-08 prospectively effective January 1, 2023 and applied the amended requirements to the acquisition of Vivint Smart Home.

Recent Accounting Developments - Guidance Not Yet Adopted

ASU 2023-07 – In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280) – Improvements to Reportable Segment Disclosures, or ASU 2023-07. The guidance in ASU 2023-07 enhances reportable segment disclosure requirements by requiring disclosure of significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss, an amount and description of its composition for other segment items and interim disclosures of a reportable segment’s profit or loss and assets. The amendments of ASU 2023-07 are effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, with early adoption permitted and should be applied retrospectively for all prior periods presented in the financial statements. The Company is currently evaluating the impact of adopting ASU 2023-07 on its disclosures.

ASU 2023-09 – In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740) – Improvements to Income Tax Disclosures, or ASU 2023-09. The guidance in ASU 2023-09 enhances income tax disclosures by requiring disclosure of specific categories in the effective tax rate reconciliation and additional information for reconciling items that meet a quantitative threshold. Further the amendments of ASU 2023-09 require certain disclosures on income tax expense and income taxes paid. ASU 2023-09 is effective for annual periods beginning after December 15, 2024, with early adoption permitted. The amendments of ASU 2023-09 may be applied on a prospective or retrospective basis. The Company is currently evaluating the impact of adopting ASU 2023-09 on its disclosures.

Note 3 — Revenue Recognition

The Company's policies with respect to its various revenue streams are detailed below. The Company generally 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.

Retail Revenue

Gross revenues for energy sales and services to retail customers are recognized as the Company transfers the promised goods and services to the customer. Payment terms are generally 15 to 60 days. For the majority of its electricity and natural gas contracts, the Company’s performance obligation with the customer is satisfied over time and performance obligations for its electricity and natural gas products are recognized as the customer takes possession of the product. The Company also allocates the contract consideration to distinct performance obligations in a contract for which the timing of the revenue recognized is different. Additionally, customer discounts and incentives reduce the contract consideration and are recognized over the term of the contract.

Energy sales and services that have been delivered but not billed by period end are estimated. Accrued unbilled revenues are based on estimates of customer usage since the date of the last meter reading provided by the independent system operators, utilities, or electric distribution companies. Volume estimates are based on daily forecasted volumes and estimated customer usage by class. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class. Estimated amounts are adjusted when actual usage is known and billed.

As contracts for retail electricity and natural gas can be for multi-year periods, 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 that vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the amount of any unsatisfied performance obligations will vary based on customer usage, which will depend on factors such as weather and customer activity and therefore it is not practicable to estimate such amounts.

Vivint Smart Home Retail Revenue

Vivint Smart Home offers its subscribers combinations of smart home products and services, which together create an integrated smart home system that allows the Company's subscribers to monitor, control and protect their homes. As the products and services included in the subscriber's contract are integrated and highly interdependent, and because the products (including installation) and services must work together to deliver the monitoring, controlling and protection of their home, the Company has concluded that the products and services contracted for by the subscriber are generally not distinct within the context of the contract and, therefore, constitute a single, combined performance obligation. Revenues for this single, combined performance obligation are recognized on a straight-line basis over the subscriber's contract term, which is the period in which the parties to the contract have enforceable rights and obligations. The Company has determined that certain contracts that do not require a long-term commitment for monitoring services by the subscriber contain a material right to renew the contract,

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because the subscriber does not have to purchase the products upon renewal. Proceeds allocated to the material right are recognized over the expected period of benefit. The majority of Vivint Smart Home's subscription contracts are five years and are generally non-cancelable. These contracts generally convert into month-to-month agreements at the end of the initial term, while some subscribers are month-to-month from inception. Payment for Vivint Smart Home services is generally due in advance on a monthly basis, with payment terms up to 30 days. Product sales and other one-time fees are invoiced to subscribers at time of sale. Revenues for any products or services that are considered separate performance obligations are recognized upon delivery. Payments received or billed in advance are reported as deferred revenues.

Energy Revenue

Both physical and financial transactions consist of revenues billed to a third-party at either market or negotiated contract terms to optimize the financial performance of the Company's generating facilities. Payment terms vary from 5 to 55 days. Electric energy revenue is recognized upon transmission to the customer over time, using the output method for measuring progress of satisfaction of performance obligations. Physical transactions, or the sale of generated electricity to meet supply and demand, are recorded on a gross basis in the Company's consolidated statements of operations. The Company applies the invoicing practical expedient in recognizing energy revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date. Financial transactions used to hedge the sale of electricity are recorded net within revenues in the consolidated statements of operations in accordance with ASC 815.

Ancillary revenues, included in Other revenue, are recognized over time as the obligation is fulfilled, using the output method for measuring progress of satisfaction of performance obligations.

Capacity Revenue

The Company's largest sources of capacity revenues are capacity auctions in PJM and NYISO. Capacity revenues also include revenues billed to a third-party at either market or negotiated contract terms for making installed generation and demand response capacity available in order to satisfy system integrity and reliability requirements. Payment terms vary from 15 to 55 days. Capacity revenues are recognized over time, using the output method for measuring progress of satisfaction of performance obligations. The Company applies the invoicing practical expedient in recognizing capacity revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date.

Performance Obligations

As of December 31, 2023, estimated future fixed fee performance obligations are $1.4 billion, $1.0 billion, $756 million, $468 million and $176 million for fiscal years 2024, 2025, 2026, 2027 and 2028, respectively. These performance obligations include Vivint Smart Home products and services as well as cleared auction MWs in the PJM, NYISO and MISO capacity auctions. The cleared auction MWs are subject to penalties for non-performance.

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Disaggregated Revenue     

The following tables represent the Company’s disaggregation of revenue from contracts with customers for the years ended December 31, 2023, 2022, and 2021:

	For the Year Ended December 31, 2023
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate/Eliminations		Total
Retail revenue
Home(b)	$	6,538	$	2,195	$	1,890	$	1,549	$	(1)	$	12,171
Business	3,492		9,751		2,053		—		—		15,296
Total retail revenue(b)	10,030		11,946		3,943		1,549		(1)		27,467
Energy revenue(c)	77		291		185		—		—		553
Capacity revenue(c)	—		197		2		—		(2)		197
Mark-to-market for economic hedging activities(d)	—		57		103		—		(16)		144
Contract amortization	—		(32)		—		—		—		(32)
Other revenue(c)	369		88		48		—		(11)		494
Total revenue	10,476		12,547		4,281		1,549		(30)		28,823
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		17		35		—		—		52
Less: Realized and unrealized ASC 815 revenue	29		364		138		—		(16)		515
Total revenue from contracts with customers	$	10,447	$	12,166	$	4,108	$	1,549	$	(14)	$	28,256
(a) Includes results of operations following the acquisition date of March 10, 2023
(b) Home includes Services and Vivint Smart Home
(c) The following amounts of retail, energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home		Corporate/Eliminations		Total
Retail revenue	$	—	$	74	$	—	$	—	$	—	$	74
Energy revenue	—		162		13		—		1		176
Capacity revenue	—		73		—		—		—		73
Other revenue	29		(2)		22		—		(1)		48
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

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	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	6,388	$	2,088	$	2,286	$	(1)	$	10,761
Business	3,229		13,768		1,964		—		18,961
Total retail revenue(b)	9,617		15,856		4,250		(1)		29,722
Energy revenue(b)	111		641		466		32		1,250
Capacity revenue(b)	—		232		40		—		272
Mark-to-market for economic hedging activities(c)	2		(30)		(56)		1		(83)
Contract amortization	—		(40)		1		—		(39)
Other revenue(b)	327		104		5		(15)		421
Total revenue	10,057		16,763		4,706		17		31,543
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(7)		41		1		35
Less: Realized and unrealized ASC 815 revenue	(2)		84		(93)		31		20
Total revenue from contracts with customers	$	10,059	$	16,686	$	4,758	$	(15)	$	31,488
(a) Home includes Services
(b) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue	$	—	$	110	$	—	$	—	$	110
Energy revenue	—		(31)		(8)		31		(8)
Capacity revenue	—		33		—		—		33
Other revenue	(4)		2		(29)		(1)		(32)
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

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	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	5,659	$	1,832	$	2,059	$	(1)	$	9,549
Business	2,745		10,030		1,237		—		14,012
Total retail revenue	8,404		11,862		3,296		(1)		23,561
Energy revenue(c)	329		508		371		7		1,215
Capacity revenue(c)	—		718		57		—		775
Mark-to-market for economic hedging activities(d)	(3)		(88)		(86)		13		(164)
Contract amortization	—		(26)		(4)		—		(30)
Other revenue(b)(c)	1,565		51		25		(9)		1,632
Total revenue	10,295		13,025		3,659		10		26,989
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(25)		3		—		(22)
Less: Realized and unrealized ASC 815 revenue	130		184		(96)		16		234
Total revenue from contracts with customers	$	10,165	$	12,866	$	3,752	$	(6)	$	26,777
(a) Home includes Services
(b) Other Revenue in Texas includes ancillary revenues of $1.3 billion driven by high pricing during Winter Storm Uri
(c) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Energy revenue	$	—	$	131	$	2	$	3	$	136
Capacity revenue	—		149		—		—		149
Other revenue	133		(8)		(12)		—		113
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

Contract Balances

The following table reflects the contract assets and liabilities included in the Company's balance sheet as of December 31, 2023 and 2022:

(In millions)	December 31, 2023		December 31, 2022
Capitalized contract costs(a)	$	706	$	126
Accounts receivable, net - Contracts with customers	3,395		4,704
Accounts receivable, net - Accounted for under topics other than ASC 606	136		64
Accounts receivable, net - Affiliate	11		5
Total accounts receivable, net	$	3,542	$	4,773
Unbilled revenues (included within Accounts receivable, net - Contracts with customers)	$	1,493	$	1,952
Deferred revenues (b)	$	1,634	$	186

(a)Amortization of capitalized contract costs for the years ended December 31, 2023, 2022 and 2021 were $168 million, $86 million and $95 million, respectively

(b)Deferred revenues from contracts with customers for the years ended December 31, 2023 and 2022 were approximately $1.6 billion and $175 million, respectively. The increase in deferred revenue balances from December 31, 2023 to 2022 was primarily due to the acquisition of Vivint Smart Home

The revenue recognized from contracts with customers during the years ended December 31, 2023 and 2022 relating to the deferred revenue balance at the beginning of each period was $168 million and $184 million, respectively. The change in the revenue recognized from contracts with customers relating to the deferred revenue balances at the beginning of the years ended December 31, 2023 and 2022 was primarily due to the timing difference of when consideration was received and when the performance obligation was transferred.

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The Company's capitalized contract costs consist of commission payments, broker fees and other costs that represent incremental costs of obtaining the contract with customers for which the Company expects to recover. Capitalized contract costs are amortized on a straight-line basis over the expected period of benefit of five years. As a practical expedient, the Company expenses the incremental costs of obtaining a contract if the amortization period of the asset would have been one year or less.

When the Company receives consideration from the customer that is in excess of the amount due, such consideration is reclassified to deferred revenue, which represents a contract liability. Smart home products and services performance obligations are recognized over the customer's contract term, which is generally three to five years. Energy contract liabilities are generally recognized to revenue in the next period as the Company satisfies its performance obligations.

Note 4 —Acquisitions and Dispositions

Acquisitions

2023 Acquisitions

Vivint Smart Home Acquisition

On March 10, 2023 (the "Acquisition Closing Date"), the Company completed the acquisition of Vivint Smart Home, Inc., pursuant to the Agreement and Plan of Merger, dated as of December 6, 2022, by and among the Company, Vivint Smart Home, Inc. and Jetson Merger Sub, Inc., a wholly-owned subsidiary of the Company (“Merger Sub”) pursuant to which Merger Sub merged with and into Vivint Smart Home, Inc., with Vivint Smart Home, Inc. surviving the merger as a wholly-owned subsidiary of the Company. Dedicated to redefining the home experience with intelligent products and services, Vivint Smart Home brought approximately two million subscribers to NRG. Vivint Smart Home's single, expandable platform incorporates artificial intelligence and machine learning into its operating system and its vertically integrated business model includes hardware, software, sales, installation, customer service and technical support and professional monitoring, enabling superior subscriber experiences and a complete end-to-end smart home experience. The acquisition accelerated the realization of NRG's consumer-focused growth strategy and creates a leading essential home services platform fueled by market-leading brands, unparalleled insights, proprietary technologies and complementary sales channels.

NRG paid $12 per share, or approximately $2.6 billion in cash. The Company funded the acquisition using:

•proceeds of $724 million from newly issued $740 million 7.000% Senior Secured First Lien Notes due 2033, net of issuance costs and discount;

•proceeds of $635 million from newly issued $650 million 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, net of issuance costs;

•proceeds of approximately $900 million drawn from its Revolving Credit Facility and Receivables Securitization Facilities; and

•cash on hand.

In February 2023, the Company increased its Revolving Credit Facility by $600 million to meet the additional liquidity requirements related to the acquisition. For further discussion, see Note 13, Long-term Debt and Finance Leases.

Acquisition costs of $38 million and $17 million for the years ended December 31, 2023 and 2022, respectively, are included in acquisition-related transaction and integration costs in the Company's consolidated statement of operations.

The acquisition has been recorded as a business combination under ASC 805, with identifiable assets and liabilities acquired recorded at their estimated Acquisition Closing Date fair value. The total consideration of $2.623 billion includes:

	(In millions)
Vivint Smart Home, Inc. common shares outstanding as of March 10, 2023 of 216,901,639 at $12.00 per share	$	2,603
Other Vivint Smart Home, Inc. equity instruments (Cash out RSUs and PSUs, Stock Appreciation Rights, Private Placement Warrants)	6
Total Cash Consideration	$	2,609
Fair value of acquired Vivint Smart Home, Inc. equity awards attributable to pre-combination service	14
Total Consideration	$	2,623

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The purchase price was allocated as follows as of December 31, 2023:

	(In millions)
Current Assets
Cash and cash equivalents	$	120
Accounts receivable, net	60
Inventory	113
Prepayments and other current assets	37
Total current assets	330
Property, plant and equipment, net	49
Other Assets
Operating lease right-of-use assets, net	35
Goodwill(a)	3,494
Intangible assets, net(b):
Customer relationships	1,740
Technology	860
Trade names	160
Sales channel contract	10
Intangible assets, net	2,770
Deferred income taxes	382
Other non-current assets	14
Total other assets	6,695
Total Assets	$	7,074
Current Liabilities
Current portion of long-term debt and finance leases	$	14
Current portion of operating lease liabilities	13
Accounts payable	109
Derivative instruments	80
Deferred revenue current	518
Accrued expenses and other current liabilities	207
Total current liabilities	941
Other Liabilities
Long-term debt and finance leases	2,572
Non-current operating lease liabilities	28
Derivative instruments	32
Deferred income taxes	18
Deferred revenue non-current	837
Other non-current liabilities	23
Total other liabilities	3,510
Total Liabilities	$	4,451
Vivint Smart Home Purchase Price	$	2,623

(a)Goodwill arising from the acquisition is attributed to the value of the platform acquired, cross-selling opportunities, subscriber growth and the synergies expected from combining the operations of Vivint Smart Home with NRG's existing businesses. None of the goodwill recorded will be deductible for tax purposes

(b)The weighted average amortization period for total amortizable intangible assets is approximately ten years

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Fair Value Measurement of Intangible Assets

The fair values of intangible assets as of the Acquisition Closing Date were measured primarily based on significant inputs that are observable and unobservable in the market and thus represent Level 2 and Level 3 measurements, respectively. Significant inputs were as follows:

Customer relationships – Customer relationships, reflective of Vivint Smart Home’s subscriber base, were valued using an excess earning method of the income approach, and is classified as Level 3. Under this approach, the Company estimated the present value of expected future cash flows resulting from existing subscriber relationships, considering attrition and charges for contributory assets (such as net working capital, fixed assets, workforce, trade names and technology) utilized in the business, discounted based on the required rate of return on the acquired intangible asset. The subscriber relationships are amortized to depreciation and amortization, ratably based on discounted future cash flows. The weighted average amortization period is twelve years.

Technology – Developed technology was valued using a "relief from royalty" method of the income approach, and is classified as Level 3. Under this approach, the fair value was estimated to be the present value of royalties saved which assumed the value of the asset based on discounted cash flows of the amount that would be paid by a hypothetical market participant had they not owned the asset and instead licensed the asset from another company. The estimated cash flows from the developed technology considered the obsolescence factor and was discounted based on the required rate of return on the acquired intangible asset. The developed technology is amortized to depreciation and amortization, ratably based on discounted future cash flows. The weighted average amortization period is five years.

Trade names – Trade names were valued using a "relief from royalty" method of the income approach, and is classified as Level 3. Under this approach, the fair value is estimated to be the present value of royalties saved which assumed the value of the asset based on discounted cash flows of the amount that would be paid by a hypothetical market participant had they not owned the asset and instead licensed the asset from another company. The estimated cash flows from the trade names considered the expected probable use of the asset and was discounted based on the required rate of return on the acquired intangible asset. The trade names are amortized to depreciation and amortization, on a straight line basis, over an amortization period of ten years.

Fair Value Measurement of Acquired Vivint Smart Home Debt

The Company acquired $2.7 billion in aggregate principal of Vivint Smart Home’s 2027 Senior Secured Notes, 2029 Senior notes and 2028 Senior Secured Term Loan (together, the "Acquired Vivint Smart Home Debt") which were recorded at fair value as of the Acquisition Closing Date. The difference between the fair value at the Acquisition Closing Date and the principal outstanding of the Acquired Vivint Smart Home Debt, of $152 million, is being amortized through interest expense over the remaining term of the debt. The Acquired Vivint Smart Home Debt is classified as Level 2 and were measured at fair value using observable market inputs based on interest rates at the Acquisition Closing Date. For additional discussion, see Note 13, Long-term Debt and Finance Leases.

Fair Value Measurement of Derivatives Liabilities

The derivative liabilities are recorded in connection with the contractual future payment obligations with the financing providers under Vivint Smart Home’s Consumer Financing Program. The fair values of the derivatives liabilities as of the Acquisition Closing Date were valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates. These derivatives are classified as Level 3 and changes to the fair value are recorded through other income, net in the consolidated statement of operations. For additional discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities.

Supplemental Pro Forma Financial Information

The following table provides unaudited pro forma combined financial information of NRG and Vivint Smart Home, after giving effect to the Vivint Smart Home acquisition and related financing transactions as if they had occurred on January 1, 2021. The pro forma financial information has been prepared for illustrative and informational purposes only, and is not intended to project future operating results or be indicative of what the Company's financial performance would have been had the transactions occurred on the date indicated. No effect has been given to prospective operating synergies.

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Total operating revenues	$	29,109	$	33,225	$	28,468
Net (loss)/income	(3)		1,136		1,574

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Amounts above reflect certain pro forma adjustments that were directly attributable to the Vivint Smart Home acquisition. These adjustments include the following:

(i)Income statement effects of fair value adjustments based on the purchase price allocation including amortization of intangible assets, reversal of historical Vivint Smart Home amortization of capitalized contract costs and reversal of historical Vivint Smart Home other income recorded for the change in fair value of warrant derivative liabilities, as the warrants are assumed to be cashed out upon the Acquisition Closing Date.

(ii)One-time expenses directly related to the acquisition.

(iii)Adjustments to reflect all acquisition and related transactions costs in the year ended December 31, 2021.

(iv)Interest expense assumes the financing transactions directly attributable to the Vivint Smart Home acquisition occurred on January 1, 2021.

(v)Adjustments related to recording Vivint Smart Home's historical debt at Acquisition Closing Date fair value.

(vi)Adjustments to reflect the write-off of short-term deferred financing costs related to the bridge facility put in place for the acquisition prior to securing permanent financing during the year ended December 31, 2021 instead of the year ended December 31, 2023.

(vii) Income tax effect of the acquisition accounting adjustments and financing adjustments (adjusted for permanent book/tax differences) based on combined blended federal/state tax rate for all periods presented.

2021 Acquisitions

Direct Energy Acquisition

On January 5, 2021, the Company acquired all of the issued and outstanding common shares of Direct Energy, which had been a North American subsidiary of Centrica plc. Direct Energy is a leading retail provider of electricity, natural gas, and home and business energy related products and services in North America, with operations in all 50 U.S. states and 8 Canadian provinces. The acquisition increased NRG's retail portfolio by over 3 million customers and strengthened its integrated model. It also broadened the Company's presence in the Northeast and into states and locales where it did not previously operate, supporting NRG's objective to diversify its business.

The Company paid an aggregate purchase price of $3.625 billion in cash and total purchase price adjustment of $99 million, resulting in an adjusted purchase price of $3.724 billion.

Acquisition costs of $25 million for the year ended December 31, 2021 are included in acquisition-related transaction and integration costs in the Company's consolidated statement of operations.

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The acquisition has been recorded as a business combination under ASC 805 with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the acquisition date. The purchase price was allocated as follows as of December 31, 2021:

	(In millions)
Current Assets
Cash and cash equivalents	$	152
Funds deposited by counterparties	21
Restricted cash	9
Accounts receivable, net	1,802
Inventory	106
Derivative instruments	1,014
Cash collateral paid in support of energy risk management activities	233
Prepayments and other current assets	173
Total current assets	3,510
Property, plant and equipment, net	151
Other Assets
Goodwill(a)	1,250
Intangible assets, net:
Customer relationships(b)	1,277
Customer and supply contracts(b)	610
Trade names(b)	310
Renewable energy credits	124
Total intangible assets, net	2,321
Derivative instruments	531
Other non-current assets	31
Total other assets	4,133
Total Assets	$	7,794
Current Liabilities
Accounts payable	$	1,116
Derivative instruments	1,266
Cash collateral received in support of energy risk management activities	21
Accrued expenses and other current liabilities	670
Total current liabilities	3,073
Other Liabilities
Derivative instruments	562
Deferred income taxes	320
Other non-current liabilities	115
Total other liabilities	997
Total Liabilities	$	4,070
Direct Energy Purchase Price	$	3,724

(a)Goodwill arising from the acquisition was attributed to the value of the platform acquired and the synergies expected from combining the operations of Direct Energy with NRG's existing businesses. Goodwill was allocated to the Texas, East, and West/Services/Other segments of $427 million, $648 million and $175 million, respectively. Goodwill deductible for tax purposes was $322 million

(b)As of January 5, 2021, the weighted average amortization period for total amortizable intangible assets was 12 years

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Dispositions

2023 Dispositions

Sale of the 44% equity interest in STP

On November 1, 2023, the Company closed on the sale of its 44% equity interest in STP to Constellation Energy Generation ("Constellation"). Proceeds of $1.75 billion were reduced by working capital and other adjustments of $96 million, resulting in net proceeds of $1.654 billion. The Company recorded a gain on the sale of $1.2 billion within the Texas region of operations. For discussion of the litigation matter related to the transaction, see Note 23, Commitments and Contingencies.

The Company recorded income before income taxes from its 44% equity interest in STP as follows:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Income before income taxes(a)	$	206	$	362	$	829

(a)Excludes the impact of the Company's hedges at the portfolio level

Sale of Gregory

On October 2, 2023, the Company closed on the sale of its 100% ownership in the Gregory natural gas generating facility in Texas for $102 million. The Company recorded a gain on the sale of $82 million.

Sale of Astoria

On January 6, 2023, the Company closed on the sale of land and related generation assets from the Astoria site, within the East region of operations, for proceeds of $212 million, subject to transaction fees of $3 million and certain indemnifications, resulting in a $199 million gain. As part of the transaction, NRG entered into an agreement to lease the land back for the purpose of operating the Astoria gas turbines. Decommissioning was completed in December 2023 and the lease agreement has been terminated.

2022 Dispositions

Sale of Watson

On June 1, 2022, the Company closed on the sale of its 49% ownership in the Watson natural gas generating facility for $59 million. The Company recorded a gain on the sale of $46 million.

2021 Dispositions

Sale of 4,850 MW of Fossil generating assets

On December 1, 2021, the Company closed the previously announced sale of approximately 4,850 MWs of fossil generating assets from its East and West regions to Generation Bridge, an affiliate of ArcLight Capital Partners. Proceeds of $760 million were reduced by working capital and other adjustments of $140 million, resulting in net proceeds of $620 million. The Company recorded a gain of $207 million from the sale, which includes the $39 million indemnification liability recorded as discussed below. As part of the transaction, NRG entered into a tolling agreement for the 866 MW Arthur Kill plant in New York City through April 2025.

As part of the agreement to sell the fossil generating assets, NRG has agreed to indemnify Generation Bridge for certain future environmental compliance costs up to $39 million. The indemnity term will expire on December 1, 2028. The Company has recorded the liability within accrued expenses and other current liabilities and other non-current liabilities.

Sale of Agua Caliente

On February 3, 2021, the Company closed on the sale of its 35% ownership in the Agua Caliente solar project to Clearway Energy, Inc. for $202 million. NRG recognized a gain on the sale of $17 million, including cash disposed of $7 million.

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Note 5 — Fair Value of Financial Instruments

For cash and cash equivalents, funds deposited by counterparties, restricted cash, accounts and other receivables, accounts payable and cash collateral paid and received in support of energy risk management activities, the carrying amount approximates fair value because of the short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy.

The estimated carrying value and fair value of the Company's long-term debt, including current portion, is as follows:

	As of December 31,
	2023				2022
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Convertible Senior Notes	$	575	$	739	$	575	$	576
Other long-term debt, including current portion	10,219		9,835		7,523		6,432
Total long-term debt, including current portion(a)	$	10,794	$	10,574	$	8,098	$	7,008

(a)Excludes deferred financing 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 and the Vivint Smart Home Senior Secured Term Loan are based on quoted market prices and are classified as Level 2 within the fair value hierarchy.

Fair Value Accounting under ASC 820

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

•Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date. NRG's financial assets and liabilities utilizing Level 1 inputs include active exchange-traded securities, energy derivatives, and trust fund investments.

•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. NRG's financial assets and liabilities utilizing Level 2 inputs include fixed income securities, exchange-based derivatives, and over the counter derivatives such as swaps, options and forward contracts.

•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. NRG's financial assets and liabilities utilizing Level 3 inputs include infrequently-traded, non-exchange-based derivatives and commingled investment funds, and are measured using present value pricing models.

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 in its entirety.

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Recurring Fair Value Measurements

Derivative assets and liabilities, debt securities, equity securities and trust fund investments, which were comprised of various U.S. debt and equity securities, are carried at fair market value.

The following tables present assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:

	As of December 31, 2023
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	21	$	—	$	21	$	—
Derivative assets:
Interest rate contracts	12		—		12		—
Foreign exchange contracts	5		—		5		—
Commodity contracts	6,138		1,334		4,470		334
Equity securities measured using net asset value practical expedient (classified within other non-current assets)	6
Total assets	$	6,182	$	1,334	$	4,508	$	334
Derivative liabilities:
Interest rate contracts	$	8	$	—	$	8	$	—
Foreign exchange contracts	9		—		9		—
Commodity contracts	5,356		1,413		3,728		215
Consumer Financing Program	134		—		—		134
Total liabilities	$	5,507	$	1,413	$	3,745	$	349

110

	As of December 31, 2022
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	19	$	—	$	19	$	—
Nuclear trust fund investments:
Cash and cash equivalents	15		15		—		—
U.S. government and federal agency obligations	86		84		2		—
Federal agency mortgage-backed securities	101		—		101		—
Commercial mortgage-backed securities	35		—		35		—
Corporate debt securities	114		—		114		—
Equity securities	403		403		—		—
Foreign government fixed income securities	1		—		1		—
Other trust fund investments (classified within other non-current assets):
U.S. government and federal agency obligations	1		1		—		—
Derivative assets:
Foreign exchange contracts	18		—		18		—
Commodity contracts	11,976		1,929		8,796		1,251
Measured using net asset value practical expedient:
Equity securities - nuclear trust fund investments	83
Equity securities (classified within other non-current assets)	6
Total assets	$	12,858	$	2,432	$	9,086	$	1,251
Derivative liabilities:
Foreign exchange contracts	$	2	$	—	$	2	$	—
Commodity contracts	8,439		1,244		6,449		746
Total liabilities	$	8,441	$	1,244	$	6,451	$	746

The following table reconciles, for the years ended December 31, 2023 and 2022, the beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs, for commodity derivatives:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Commodity Derivatives (a)
	For the Year Ended December 31,
(In millions)	2023		2022
Beginning balance	$	505	$	293
Total (losses)/gains realized/unrealized included in earnings	(164)		53
Purchases	42		(110)
Transfers into Level 3(b)	78		264
Transfers out of Level 3(b)(c)	(342)		5
Ending balance	$	119	$	505
(Losses)/gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of year-end	$	(46)	$	204

(a)Consists of derivatives assets and liabilities, net, excluding derivative liabilities from Consumer Financing Program, which are presented in a separate table below

(b)Transfers into/out of Level 3 are related to the availability of consensus pricing and external broker quotes, and are valued as of the end of the reporting period. All transfers into/out of Level 3 are from/to Level 2

(c)For the year ended December 31, 2023, due to the change to use consensus pricing, there was a decrease in the number of contracts valued with prices provided by models and other valuation techniques, which resulted in a large transfer out of Level 3

Realized and unrealized gains and losses included in earnings that are related to the commodity derivatives are recorded in revenues and cost of operations.

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The following table reconciles, for the year ended December 31, 2023, the beginning and ending balances of the contractual obligations from the Consumer Financing Program that are recognized at fair value in the condensed consolidated financial statements, using significant unobservable inputs:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Consumer Financing Program
(In millions)	For the Year Ended December 31, 2023
Beginning balance	$	—
Contractual obligations added from the acquisition of Vivint Smart Home	(112)
New contractual obligations	(68)
Settlements	62
Total losses included in earnings	(16)
Ending balance	$	(134)

Gains and losses that are related to the Consumer Financing Program derivative are recorded in other income, net.

Non-derivative fair value measurements

For the year ended December 31, 2022 and through the sale of STP on November 1, 2023, the trust fund investments were held primarily to satisfy NRG's nuclear decommissioning obligations. These trust fund investments held debt and equity securities directly and equity securities indirectly through commingled funds. The fair values of equity securities held directly by the trust funds were based on quoted prices in active markets and were categorized in Level 1. In addition, U.S. government and federal agency obligations were categorized as Level 1 because they traded in a highly liquid and transparent market. The fair values of corporate debt securities were based on evaluated prices that reflected observable market information, such as actual trade information of similar securities, adjusted for observable differences and were categorized in Level 2. Certain equity securities, classified as commingled funds, were analogous to mutual funds, were maintained by investment companies, and held certain investments in accordance with a stated set of fund objectives. The fair value of the equity securities classified as commingled funds were based on net asset values per fund share (the unit of account), derived from the quoted prices in active markets of the underlying equity securities. However, because the shares in the commingled funds were not publicly quoted and not traded in an active market, the commingled funds were measured using net asset value practical expedient. See also Note 7, Nuclear Decommissioning Trust Fund.

Derivative fair value measurements

The Company's contracts consist of non-exchange-traded contracts valued using prices provided by external sources and exchange-traded contracts with readily available quoted market prices. Beginning in of the fourth quarter of 2023 and as of December 31, 2023, the fair value of non-exchange traded contracts were based on consensus pricing provided by independent pricing services. The pricing data was compiled from market makers with longer dated tenors as compared to broker quotes, enhancing reliability and increasing transparency.

Prior to the fourth quarter of 2023, the Company valued derivatives based on price quotes from brokers in active markets who regularly facilitate those transactions. For the majority of markets that NRG participates in, the Company would receive broker quotes from multiple sources and reflected the average of the bid-ask mid-point prices. The terms for which such price information is available vary by commodity, region and product. The Company believes both sources of price quotes are executable.

The remainder of the assets and liabilities represents 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 observable market data with similar characteristics. As of December 31, 2023, contracts valued with prices provided by models and other valuation techniques make up 5% of derivative assets and 6% of derivative liabilities. As a result of NRG switching to consensus pricing as of December 31, 2023, there was a significant decrease in the number of contracts valued with prices provided by models and other valuation techniques. The fair value of each contract is discounted using a risk free interest rate. In addition, the Company applies a credit reserve to reflect credit risk, which for foreign exchange contracts and interest rate swaps is calculated utilizing the bilateral method based on published default probabilities. For commodities, to the extent that NRG's net exposure under a specific master agreement is an asset, the Company uses the counterparty's default swap rate. If the exposure under a specific master agreement is a liability, the Company uses NRG's default swap rate. For foreign exchange contracts, 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 NRG's liabilities or that a market participant would be willing to pay for NRG's assets. As of December 31, 2023, the credit reserve resulted in a $18 million decrease primarily within cost of operations. As of December 31, 2022, the credit reserve resulted in $9 million decrease primarily within cost of operations.

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The fair values in each category reflect the level of forward prices and volatility factors as of December 31, 2023 and may change as a result of changes in these factors. Management uses its best estimates to determine the fair value of commodity and derivative contracts NRG holds and sells. These estimates consider various factors including closing exchange, consensus and over-the-counter price quotations, time value, volatility factors and credit exposure. It is possible, however, that future market prices could vary from those used in recording assets and liabilities from energy marketing and trading activities and such variations could be material.

NRG's significant positions classified as Level 3 include physical and financial natural gas, power, capacity contracts and renewable energy certificates executed in illiquid markets as well as financial transmission rights ("FTRs"). The significant unobservable inputs used in developing fair value include illiquid natural gas and power location pricing, which is derived as a basis to liquid locations. The basis spread is based on observable market data when available or derived from historic prices and forward market prices from similar observable markets when not available. Forward capacity prices are based on market information, forecasted future electricity demand and supply, past auctions and internally developed pricing models. Renewable energy certificate prices are based on market information and internally developed pricing models. For FTRs, NRG uses the most recent auction prices to derive the fair value. The Consumer Financing Program derivatives are valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates.

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company's Level 3 positions as of December 31, 2023 and 2022:

	Significant Unobservable Inputs
	December 31, 2023
	Fair Value						Input/Range
(in millions, except as noted)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low			High			Weighted Average
Natural Gas Contracts	$	39	$	65	Discounted Cash Flow	Forward Market Price ($ per MMBtu)	$	1		$	15		$	3
Power Contracts	197		66		Discounted Cash Flow	Forward Market Price ($ per MWh)	1			210			47
Capacity Contracts	21		33		Discounted Cash Flow	Forward Market Price ($ per MW/Day)	49			658			285
Renewable Energy Certificates	58		14		Discounted Cash Flow	Forward Market Price ($ per Certificate)	2			320			15
FTRs	19		37		Discounted Cash Flow	Auction Prices ($ per MWh)	(58)			252			0
Consumer Financing Program	—		134		Discounted Cash Flow	Collateral Default Rates	0.43		%	93.30		%	8.12		%
					Discounted Cash Flow	Collateral Prepayment Rates	2.00		%	3.00		%	2.95		%
					Discounted Cash Flow	Credit Loss Rates	6.00		%	60.00		%	12.57		%
	$	334	$	349

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	Significant Unobservable Inputs
	December 31, 2022
	Fair Value						Input/Range
(in millions, except as noted)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
Natural Gas Contracts	$	340	$	448	Discounted Cash Flow	Forward Market Price ($ per MMBtu)	$	2	$	48	$	6
Power Contracts	843		216		Discounted Cash Flow	Forward Market Price ($ per MWh)	3		431		48
FTRs	68		82		Discounted Cash Flow	Auction Prices ($ per MWh)	(32)		610		0
	$	1,251	$	746

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2023 and 2022:

Significant Unobservable Input	Position	Change In Input	Impact on Fair Value Measurement
Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates	Buy	Increase/(Decrease)	Higher/(Lower)
Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates	Sell	Increase/(Decrease)	Lower/(Higher)
FTR Prices	Buy	Increase/(Decrease)	Higher/(Lower)
FTR Prices	Sell	Increase/(Decrease)	Lower/(Higher)
Collateral Default Rates	n/a	Increase/(Decrease)	Higher/(Lower)
Collateral Prepayment Rates	n/a	Increase/(Decrease)	Lower/(Higher)
Credit Loss Rates	n/a	Increase/(Decrease)	Higher/(Lower)

Under the guidance of ASC 815, entities may choose to offset cash collateral posted or received against the fair value of derivative positions executed with the same counterparties under the same master netting agreements. The Company has chosen not to offset positions as defined in ASC 815. As of December 31, 2023, the Company recorded $441 million of cash collateral posted and $84 million of cash collateral received on its balance sheet.

Concentration of Credit Risk

In addition to the credit risk discussion as disclosed in Note 2, Summary of Significant Accounting Policies, the following item is a discussion of the concentration of credit risk for the Company's financial instruments. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; (ii) a daily monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties. The Company also has credit protection within various agreements to call on additional collateral support if and when necessary. Cash margin is collected and held at the Company to cover the credit risk of the counterparty until positions settle.

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Counterparty Credit Risk

As of December 31, 2023, counterparty credit exposure, excluding credit exposure from RTOs, ISOs, and registered commodity exchanges and certain long-term agreements, was $1.6 billion and NRG held collateral (cash and letters of credit) against those positions of $426 million, resulting in a net exposure of $1.2 billion. NRG periodically receives collateral from counterparties in excess of their exposure. Collateral amounts shown include such excess while net exposure shown excludes excess collateral received. Approximately 63% of the Company's exposure before collateral is expected to roll off by the end of 2025. Counterparty credit exposure is valued through observable market quotes and discounted at a risk free interest rate. The following tables highlight net counterparty credit exposure by industry sector and by counterparty credit quality. Net counterparty credit exposure is defined as the aggregate net asset position for NRG with counterparties where netting is permitted under the enabling agreement and includes all cash flow, mark-to-market and NPNS, and non-derivative transactions. The exposure is shown net of collateral held and includes amounts net of receivables or payables.

Category	Net Exposure (a) (b) (% of Total)
Utilities, energy merchants, marketers and other	80	%
Financial institutions	20
Total	100	%

Category	Net Exposure (a) (b) (% of Total)
Investment grade	44	%
Non-Investment grade/Non-Rated	56
Total	100	%

(a)Counterparty credit exposure excludes coal transportation contracts because of the unavailability of market prices

(b)The figures in the tables above exclude potential counterparty credit exposure related to RTOs, ISOs, registered commodity exchanges and certain long term contracts

The Company currently has exposure to one wholesale counterparty in excess of 10% of the total net exposure discussed above as of December 31, 2023. Changes in hedge positions and market prices will affect credit exposure and counterparty concentration.

RTOs and ISOs

The Company participates in the organized markets of CAISO, ERCOT, AESO, IESO, ISO-NE, MISO, NYISO and PJM, known as RTOs or ISOs. Trading in the majority of these markets is approved by FERC, whereas in the case of ERCOT, it is approved by the PUCT, and whereas in the case of AESO and IESO, both exist provincially with AESO primarily subject to Alberta Utilities Commission and the IESO subject to the Ontario Energy Board. These ISOs may include credit policies that, under certain circumstances, require that losses arising from the default of one member on spot market transactions be shared by the remaining participants. As a result, the counterparty credit risk to these markets is limited to NRG’s share of the overall market and are excluded from the above exposures.

Exchange Traded Transactions

The Company enters into commodity transactions on registered exchanges, notably ICE, NYMEX and Nodal. These clearinghouses act as the counterparty and transactions are subject to extensive collateral and margining requirements. As a result, these commodity transactions have limited counterparty credit risk.

Long-Term Contracts

Counterparty credit exposure described above excludes credit risk exposure under certain long term contracts, primarily solar under Renewable PPAs. As external sources or observable market quotes are not always available to estimate such exposure, the Company values these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. Based on these valuation techniques, as of December 31, 2023, aggregate credit risk exposure managed by NRG to these counterparties was approximately $882 million for the next five years.

Retail Customer Credit Risk

The Company is exposed to retail credit risk through the Company's retail electricity and gas providers, which serve Home and Business customers. Retail credit risk results in losses when a customer fails to pay for services rendered. The losses may result from both nonpayment of customer accounts receivable and the loss of in-the-money forward value. The Company manages retail credit risk through the use of established credit policies that include monitoring of the portfolio and the use of credit mitigation measures such as deposits or prepayment arrangements.

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As of December 31, 2023, the Company's retail customer credit exposure to Home and Business customers was diversified across many customers and various industries, as well as government entities. Current economic conditions may affect the Company's customers' ability to pay bills in a timely manner, which could increase customer delinquencies and may lead to an increase in credit losses. The Company's provision for credit losses was $251 million, $11 million, and $698 million for the years ended December 31, 2023, 2022, and 2021, respectively. During the year ended December 31, 2022, the provision for credit losses included the Company's loss mitigation efforts recognized as income of $126 million related to Winter Storm Uri. During the year ended December 31, 2021, the provision for credit losses included $596 million of expenses due to the impacts of Winter Storm Uri.

Note 6 — Accounting for Derivative Instruments and Hedging Activities

ASC 815 requires the Company to recognize all derivative instruments on the balance sheet as either assets or liabilities and to measure them at fair value each reporting period unless they qualify for a NPNS exception. The Company may elect to designate certain derivatives as cash flow hedges, if certain conditions are met, and defer the change in fair value of the derivatives to accumulated OCI, until the hedged transactions occur and are recognized in earnings.

For derivatives that are not designated as cash flow hedges or do not qualify for hedge accounting treatment, the changes in the fair value will be immediately recognized in earnings. Certain derivative instruments may qualify for the NPNS exception and are therefore exempt from fair value accounting treatment. ASC 815 applies to NRG's energy related commodity contracts, foreign exchange contracts, interest rate swaps and Consumer Financing Program.

As the Company engages principally in the trading and marketing of its generation assets and retail operations, some of NRG's commercial activities qualify for NPNS accounting. Most of the retail load contracts either qualify for the NPNS exception or fail to meet the criteria for a derivative and the majority of the retail supply and fuels supply contracts are recorded under mark-to-market accounting. All of NRG's hedging and trading activities are subject to limits within the Company's Risk Management Policy.

Energy-Related Commodities

To manage the commodity price risk associated with the Company's competitive supply activities and the price risk associated with wholesale power sales from the Company's electric generation facilities and retail power and gas sales from NRG's retail operations, NRG enters into a variety of derivative and non-derivative hedging instruments, utilizing the following:

•Forward contracts, which commit NRG to purchase or sell energy commodities or fuels in the future;

•Futures contracts, which are exchange-traded standardized commitments to purchase or sell a commodity or financial instrument;

•Swap agreements, which require payments to or from counterparties based upon the differential between two prices for a predetermined contractual, or notional, quantity;

•Option contracts, which convey to the option holder the right but not the obligation to purchase or sell a commodity; and

•Weather derivative products used to mitigate a portion of lost revenue due to weather.

The objectives for entering into derivative contracts designated as hedges include:

•Fixing the price of a portion of anticipated power and gas purchases for the Company's retail sales;

•Fixing the price for a portion of anticipated future electricity sales that provides an acceptable return on the Company's electric generation operations; and

•Fixing the price of a portion of anticipated fuel purchases for the operation of the Company's power plants.

These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative financial instruments are recognized in earnings.

As of December 31, 2023, NRG's derivative assets and liabilities consisted primarily of the following:

•Forward and financial contracts for the purchase/sale of electricity and related products economically hedging NRG's generation assets' forecasted output or NRG's retail load obligations through 2036;

•Forward and financial contracts for the purchase of fuel commodities relating to the forecasted usage of NRG's generation assets through 2025;

•Other energy derivatives instruments extending through 2029.

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Also, as of December 31, 2023, NRG had other energy-related contracts that did not meet the definition of a derivative instrument or qualified for the NPNS exception and were therefore exempt from fair value accounting treatment as follows:

•Load-following forward electric sale contracts extending through 2036;

•Load-following forward natural gas purchase and sale contracts extending through 2032;

•Power tolling contracts through 2036;

•Coal purchase contracts through 2024;

•Power transmission contracts through 2029;

•Natural gas transportation contracts through 2034;

•Natural gas storage agreements through 2030; and

•Coal transportation contracts through 2029.

Foreign Exchange Contracts

In order to mitigate foreign exchange risk primarily associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements through 2027.

Interest Rate Swaps

NRG is exposed to changes in interest rate through the Company's issuance of variable rate debt. To manage the Company's interest rate risk, NRG enters into interest rate swap agreements. In the first quarter of 2023, the Company entered into $1.0 billion of interest rate swaps through 2027 to hedge the floating rate on the Term Loan acquired with the Vivint Smart Home acquisition. Additionally, in the first quarter of 2023, the Company had entered into interest rate swaps to hedge the floating rate on the Revolving Credit Facility extending through 2024, which was fully terminated in conjunction with the pay down of the Revolving Credit Facility.

Consumer Financing Program

Under the Consumer Financing Program, Vivint Smart Home pays a monthly fee to Financing Providers based on either the average daily outstanding balance of the loans or the number of outstanding loans. For certain loans, Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees. Vivint Smart Home also shares the liability for credit losses, depending on the credit quality of the subscriber. Due to the nature of certain provisions under the Consumer Financing Program, the Company records a derivative liability that is not designated as a hedging instrument and is adjusted to fair value, measured using the present value of the estimated future payments. Changes to the fair value are recorded through other income, net in the consolidated statement of operations. The following represent the contractual future payment obligations with the Financing Providers under the Consumer Financing Program that are components of the derivative:

•    Vivint Smart Home pays either a monthly fee based on the average daily outstanding balance of the loans, or the number of outstanding loans, depending on the Financing Provider;

•    Vivint Smart Home shares the liability for credit losses depending on the credit quality of the subscriber; and

•    Vivint Smart Home pays transactional fees associated with subscriber payment processing.

The derivative is classified as a Level 3 instrument. The derivative positions are valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates. In summary, the fair value represents an estimate of the present value of the cash flows Vivint Smart Home will be obligated to pay to the Financing Provider for each component of the derivative.

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Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy/(sell) of NRG's open derivative transactions broken out by commodity, excluding those derivatives that qualified for the NPNS exception as of December 31, 2023 and 2022. Option contracts are reflected using delta volume. Delta volume equals the notional volume of an option adjusted for the probability that the option will be in-the-money at its expiration date.

		Total Volume (In millions)
Category	Units	December 31, 2023	December 31, 2022
Emissions	Short Ton	—	1
Renewables Energy Certificates	Certificates	12	15
Coal	Short Ton	9	11
Natural Gas	MMBtu	838	422
Oil	Barrels	—	1
Power	MWh	201	192
Interest	Dollars	1,000	—
Foreign Exchange	Dollars	548	569
Consumer Financing Program	Dollars	1,116	—

Fair Value of Derivative Instruments

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

	Fair Value
	Derivative Assets				Derivative Liabilities
(In millions)	December 31, 2023		December 31, 2022		December 31, 2023		December 31, 2022
Derivatives Not Designated as Cash Flow or Fair Value Hedges:
Interest rate contracts - current	$	12	$	—	$	—	$	—
Interest rate contracts - long-term	—		—		8		—
Foreign exchange contracts - current	3		11		4		1
Foreign exchange contracts - long-term	2		7		5		1
Commodity contracts- current	3,847		7,875		3,922		6,194
Commodity contracts- long-term	2,291		4,101		1,434		2,245
Consumer Financing Program - current	—		—		93		—
Consumer Financing Program - long-term	—		—		41		—
Total Derivatives Not Designated as Cash Flow or Fair Value Hedges	$	6,155	$	11,994	$	5,507	$	8,441

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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. In addition, collateral received or paid on the Company's derivative assets or liabilities are recorded on a separate line item on the balance sheet. The following table summarizes the offsetting derivatives by counterparty master agreement level and collateral received or paid:

	Gross Amounts Not Offset in the Statement of Financial Position
(In millions)	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Cash Collateral (Held)/Posted		Net Amount
As of December 31, 2023
Interest rate contracts:
Derivative assets	$	12	$	(8)	$	—	$	4
Derivative liabilities	(8)		8		—		—
Total interest rate contracts	4		—		—		4
Foreign exchange contracts:
Derivative assets	$	5	$	(5)	$	—	$	—
Derivative liabilities	(9)		5		—		(4)
Total foreign exchange contracts	$	(4)	$	—	$	—	$	(4)
Commodity contracts:
Derivative assets	$	6,138	$	(4,926)	$	(74)	$	1,138
Derivative liabilities	(5,356)		4,926		145		(285)
Total commodity contracts	$	782	$	—	$	71	$	853
Consumer Financing Program:
Derivative liabilities	$	(134)	$	—	$	—	$	(134)
Total derivative instruments	$	648	$	—	$	71	$	719

	Gross Amounts Not Offset in the Statement of Financial Position
(In millions)	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Cash Collateral (Held)/Posted		Net Amount
As of December 31, 2022
Foreign exchange contracts:
Derivative assets	$	18	$	(2)	$	—	$	16
Derivative liabilities	(2)		2		—		—
Total foreign exchange contracts	$	16	$	—	$	—	$	16
Commodity contracts:
Derivative assets	$	11,976	$	(7,897)	$	(1,659)	$	2,420
Derivative liabilities	(8,439)		7,897		20		(522)
Total commodity contracts	$	3,537	$	—	$	(1,639)	$	1,898
Total derivative instruments	$	3,553	$	—	$	(1,639)	$	1,914

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Impact of Derivative Instruments on the Statement of Operations

Unrealized gains and losses associated with changes in the fair value of derivative instruments that are not accounted for as cash flow hedges are reflected in current period results of operations.

The following table summarizes the pre-tax effects of economic hedges that have not been designated as cash flow hedges or fair value hedges and trading activity on the Company's statement of operations. The effect of foreign exchange and commodity hedges is included within revenues and cost of operations. The effect of the interest rate contracts are included within interest expense. The effect of the Consumer Financing Program is included in other income, net.

	Year Ended December 31,
(In millions)	2023		2022		2021
Unrealized mark-to-market results
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$	(1,734)	$	(1,232)	$	(41)
Reversal of acquired loss positions related to economic hedges	20		2		256
Net unrealized (losses)/gains on open positions related to economic hedges	(1,149)		2,478		2,501
Total unrealized mark-to-market (losses)/gains for economic hedging activities	(2,863)		1,248		2,716
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	13		13		(18)
Reversal of acquired (gain) positions related to trading activity	—		—		(1)
Net unrealized gains/(losses) on open positions related to trading activity	25		(17)		(13)
Total unrealized mark-to-market gains/(losses) for trading activity	38		(4)		(32)
Total unrealized (losses)/gains - commodities and foreign exchange	$	(2,825)	$	1,244	$	2,684

	Year Ended December 31,
(In millions)	2023		2022		2021
Total impact to statement of operations - interest rate contracts	$	4	$	—	$	—
Unrealized gains/(losses) included in revenues - commodities	$	182	$	(87)	$	(196)
Unrealized (losses)/gains included in cost of operations - commodities	(2,988)		1,315		2,880
Unrealized (losses)/gains included in cost of operations - foreign exchange	(19)		16		—
Total impact to statement of operations - commodities and foreign exchange	$	(2,825)	$	1,244	$	2,684
Total impact to statement of operations - Consumer Financing Program	$	(16)	$	—	$	—

        

The reversals of acquired loss/(gain) positions were valued based upon the forward prices on the acquisition date. The roll-off amounts were offset by realized gains or losses at the settled prices and are reflected in revenue or cost of operations during the same period.

The loss from open economic hedge positions of $1.1 billion for the year ended December 31, 2023 was primarily the result of a decrease in the value of forward positions as a result of decreases in natural gas and power prices in the East and West.

The gains from open economic hedge positions of $2.5 billion for the years ended December 31, 2022 and 2021 were primarily the result of an increase in value of forward positions as a result of increases in natural gas and power prices.

Credit Risk Related Contingent Features

Certain of the Company's hedging and trading agreements contain provisions that entitle the counterparty to demand that the Company post additional collateral if the counterparty determines that there has been deterioration in the Company's credit quality, generally termed “adequate assurance” under the agreements, or require the Company to post additional collateral if there were a downgrade in the Company's credit rating. The collateral potentially required for contracts with adequate assurance clauses that are in net liability positions as of December 31, 2023 was $600 million. The Company is also a party to certain marginable agreements under which it has a net liability position, but the counterparty has not called for the collateral due, which was approximately $80 million as of December 31, 2023. In the event of a downgrade in the Company's credit rating and

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if called for by the counterparty, $8 million of additional collateral would be required for all contracts with credit rating contingent features as of December 31, 2023.

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

Note 7—Nuclear Decommissioning Trust Fund

Through the sale of the Company's 44% equity interest in STP on November 1, 2023, NRG's Nuclear Decommissioning Trust Fund assets, which were for the decommissioning of STP, were comprised of securities classified as available-for-sale and recorded at fair value based on actively quoted market prices. NRG accounted for the Nuclear Decommissioning Trust Fund in accordance with ASC 980, Regulated Operations, or ASC 980, because the Company's nuclear decommissioning activities were subject to approval by the PUCT, with regulated rates that are designed to recover all decommissioning costs and that can be charged to and collected from the ratepayers per PUCT mandate. Since the Company was in compliance with PUCT rules and regulations regarding decommissioning trusts and the cost of decommissioning was the responsibility of the Texas ratepayers, not NRG, all realized and unrealized gains or losses (including other-than-temporary impairments) related to the Nuclear Decommissioning Trust Fund were recorded to the Nuclear Decommissioning Trust liability and were not included in net income or accumulated other comprehensive income, consistent with regulatory treatment.

Following the sale of the Company's 44% equity interest in STP on November 1, 2023, the Company is no longer responsible for the decommissioning of STP and no longer holds the Nuclear Decommissioning Trust Fund assets. For further discussion of the sale, see Note 4, Acquisitions and Dispositions.

The following table summarizes the aggregate fair values and unrealized gains and losses for the securities held in the trust funds as of December 31, 2022, as well as information about the contractual maturities of those securities as of that date.

	As of December 31, 2022
(In millions, except otherwise noted)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted- average maturities (in years)
Cash and cash equivalents	$	15	$	—	$	—	—
U.S. government and federal agency obligations	86		—		5		11
Federal agency mortgage-backed securities	101		—		11		26
Commercial mortgage-backed securities	35		—		4		30
Corporate debt securities	114		—		13		12
Equity securities	486		346		3		—
Foreign government fixed income securities	1		—		—		17
Total	$	838	$	346	$	36

The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from these sales for the ten months ended October 31, 2023, and for the years ended December 31, 2022 and 2021. The cost of securities sold was determined using the specific identification method.

(In millions)	2023		2022		2021
Realized gains	$	11	$	14	$	47
Realized losses	(19)		(25)		(9)
Proceeds from sale of securities	355		448		710

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Note 8 — Inventory

Inventory consisted of:

	As of December 31,
(In millions)	2023		2022
Fuel oil	$	8	$	8
Coal	178		114
Natural gas	189		385
Spare parts	68		136
Finished goods	164		108
Total Inventory	$	607	$	751

Note 9 — Property, Plant and Equipment

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

	As of December 31,				Depreciable
(In millions)	2023		2022		Lives
Facilities and equipment	$	1,918	$	1,727	1-40 years
Land and improvements	256		263
Nuclear fuel	—		271		5 years
Hardware and office equipment and furnishings	732		712		2-10 years
Construction in progress	152		197
Total property, plant, and equipment	3,058		3,170
Accumulated depreciation	(1,295)		(1,478)
Net property, plant, and equipment	$	1,763	$	1,692

Depreciation expense of property, plant and equipment recorded during the years ended December 31, 2023, 2022 and 2021 was $257 million, $291 million and $384 million, respectively.

Note 10 — Leases

The Company leases generating facilities, land, office and equipment, railcars, fleet vehicles and storefront space at retail stores. Operating leases with an initial term greater than twelve months are recognized as right-of-use assets and lease liabilities in the consolidated balance sheets. The Company made an accounting policy election, as permitted by ASC 842, for all asset classes not to recognize right-of-use assets and lease liabilities in the consolidated balance sheets for its short-term leases, which are leases that have a lease term of twelve months or less. For the initial measurement of lease liabilities, the discount rate that the Company uses is either the rate implicit in the lease, if known, or its incremental borrowing rate, which is the rate of interest that the Company would have to pay to borrow, on a collateralized basis, over a similar term an amount equal to the payments for the lease. The Company recognizes lease expense for all operating leases on a straight-line basis over the lease term. In the future, should another systematic basis become more representative of the pattern in which the lessee expects to consume the remaining economic benefit of the right-of-use asset, the Company will use that basis for lease expense.

The Company considers a contract to be or to contain a lease when both of the following conditions apply: 1) an asset is either explicitly or implicitly identified in the contract and 2) the contract conveys to the Company the right to control the use of the identified asset for a period of time. The Company has the right to control the use of the identified asset when the Company has both the right to obtain substantially all the economic benefits from the use of the identified asset and the right to direct how and for what purpose the identified asset is used throughout the period of use.

Lease payments are typically fixed and payable on a monthly, quarterly, semi-annual or annual basis. Lease payments under certain agreements may escalate over the lease term either by a fixed percentage or a fixed dollar amount. Certain leases may provide for variable lease payments in the form of payments based on unit availability, usage, a percentage of sales from the location under lease, or index-based (e.g., the U.S. Consumer Price Index) adjustments to lease payments. The Company has no leases which contain residual value guarantees provided by the Company as a lessee.

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Lease Cost:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Finance lease cost	$	8	$	4	$	4
Amortization of right-of-use assets	7		4		4
Interest on lease liabilities	1		—		—
Operating lease cost	93		85		91
Short-term lease cost	42		7		3
Variable lease cost	91		86		9
Sublease income	(2)		(2)		(2)
Total lease cost	$	232	$	180	$	105

Other information:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	195	$	183	$	102
Financing cash flows from finance leases	7		5		6
Right-of-use assets obtained in exchange for new finance lease liabilities	17		3		16
Right-of-use assets obtained in exchange for new operating lease liabilities	52		28		47

Lease Term and Discount Rate for leases:

	December 31, 2023		December 31, 2022
Finance leases:
Weighted average remaining lease term (in years)	2.9		2.6
Weighted average discount rate	4.87	%	2.82	%
Operating leases:
Weighted average remaining lease term (in years)	3.6		4.3
Weighted average discount rate	6.00	%	5.37	%

As of December 31, 2023, annual payments based on the maturities of the Company's operating leases are expected to be as follows:

	In millions
2024	$	118
2025	86
2026	34
2027	24
2028	17
Thereafter	32
Total undiscounted lease payments	$	311
Less: present value adjustment	(93)
Total discounted lease payments	$	218

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Note 11 — Asset Impairments

2023 Impairment Losses

During the fourth quarter of 2023, the Company completed its annual budget and analyzed the corresponding impact on estimated cash flows associated with its long-lived assets. The fair value of the assets was determined using an income approach by applying a discounted cash flow methodology to the long-term budget for each facility. The income approach utilized estimates of after-tax cash flows, which were Level 3 fair value measurements, and included key inputs such as forecasted power prices, fuel costs, operating and maintenance costs, plant investment capital expenditures and discount rates.

Gladstone — The Company recorded impairment losses of $102 million on its equity method investment in Gladstone within the West/Services/Other segment as a result of changes in the long-term outlook of the Gladstone facility, prompted by evolving energy policy conditions in Australia and an assessment of the long-term operational landscape of the facility, which concluded with the annual budget process. For further discussion of the Gladstone investment, see Note 17, Investments Accounted for by the Equity Method and Variable Interest Entities.

Other Impairments — The Company additionally recorded impairment losses related to property plant and equipment and leases of $2 million, $4 million and $20 million in the Texas, East and West/Services/Other segments, respectively.

2022 Impairment Losses

Astoria Redevelopment Impairment — During the third quarter of 2022, the Company entered into a purchase and sale agreement for the sale of the land and related assets at the Astoria generating site and the planned withdrawal and cancellation of its proposed Astoria redevelopment project. As a result, the Company impaired $43 million of Astoria project spend in the East segment. For further discussion of the transaction, see Note 4, Acquisitions and Dispositions.

PJM Asset Impairments — During the second quarter of 2022, the results of the PJM Base Residual Auction for the 2023/2024 delivery year were released leading the Company to revise its long-term view of certain facilities and announce the planned retirement of the Joliet generating facility. The Company considered the near-term retirement date of Joliet and the decline in PJM capacity prices to be a trigger for impairment and performed impairment tests on the PJM generating assets and the goodwill associated with Midwest Generation. The Company measured the impairment losses on the PJM generating assets and Midwest Generation goodwill as the difference between the carrying amount and the fair value of the PJM generating assets and Midwest Generation reporting unit, respectively. Fair values were determined using an income approach in which the Company applied a discounted cash flow methodology to the long-term budgets for the plants and reporting unit. Significant inputs impacting the income approach include the Company's long-term view of capacity and fuel prices, projected generation, the physical and economic characteristics of each plant and the reporting unit as a whole, and the discount rate applied to the after-tax cash flow projections. Impairment losses of $20 million and $130 million were recorded in the East segment on the PJM generating assets and Midwest Generation goodwill, respectively.

Other Impairments — The Company additionally recorded impairment losses of $13 million in the East segment.

2021 Impairment Losses

During the fourth quarter of 2021, the Company completed its annual budget and analyzed the corresponding impact on estimated cash flows associated with its long-lived assets. The fair value of the assets was determined using an income approach by applying a discounted cash flow methodology to the long-term budget for the facility. The income approach utilized estimates of after-tax cash flows, which were Level 3 fair value measurements, and included key inputs such as forecasted power prices, fuel costs, operating and maintenance costs, plant investment capital expenditures and discount rates.

Joliet —The Company recognized an impairment loss of $213 million in the East segment as a result of changes in the long-term outlook of the Joliet facility prompted by market conditions and an assessment of various alternatives for the long-term operational landscape of the facility including the impact of the CEJA in Illinois, which concluded with the annual budget process.

Other Impairments — The Company additionally recorded impairment losses of $16 million and $9 million related to various power plants in the East and West/Service/Other segments, respectively.

The Company also recorded the following impairment in 2021 based on a specific triggering event that occurred using the same methodology previously discussed:

PJM Asset Impairments — During the second quarter of 2021, the results of the PJM Base Residual Auction for the 2022/2023 delivery year were released leading the Company to announce the near-term retirement of a significant portion of its PJM coal generating assets in June 2022. The Company considered the decline in PJM capacity prices and the near-term retirement dates of certain assets to be a trigger for impairment and performed impairment tests on the PJM generating assets and the goodwill associated with Midwest Generation. Impairment losses of $271 million and $35 million were recorded in the East segment on the PJM generating assets and Midwest Generation goodwill, respectively.

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Note 12 — Goodwill and Other Intangibles

Goodwill

The table below presents the changes of goodwill for the years ended December 31, 2023 and 2022 based on the Company's reportable segments.

(in millions)	Texas		East		West/Services/Other		Vivint Smart Home		Total
Balance as of January 1, 2022	$	716	$	853	$	226	$	—	$	1,795
Impairment losses	—		(130)		—		—		(130)
Asset sales	(6)		—		—		—		(6)
Foreign currency translation	—		—		(9)		—		(9)
Balance as of December 31, 2022	$	710	$	723	$	217	$	—	$	1,650
Goodwill resulted from the acquisition of Vivint	—		—		—		3,494		3,494
Asset sales	(67)		(2)		—		—		(69)
Foreign currency translation	—		—		4		—		4
Balance as of December 31, 2023	$	643	$	721	$	221	$	3,494	$	5,079

Intangible Assets

The Company's intangible assets as of December 31, 2023, primarily reflect intangible assets established with the acquisitions of various companies, including Vivint Smart Home, Direct Energy, Stream Energy, other retail acquisitions and Texas Genco. Intangible assets are comprised of the following:

•Emission Allowances — These intangibles primarily consist of SO2 emission allowances, including those established with the 2006 acquisition of Texas Genco, RGGI emission credits and California carbon allowances. These emission allowances are held-for-use and are amortized to cost of operations based on units of production.

•Customer and supply contracts — These intangibles include the fair value at the acquisition date of in-market and out-of-market customer and supply contracts from the acquisition of Direct Energy and are amortized to revenue and cost of operations, respectively, based upon the fair market value, as of the acquisition date, for each delivery month.

•Customer relationships — These intangibles represent the fair value at the acquisition date of acquired businesses' customer base from the acquisition of Vivint, Direct Energy and other acquisitions. Customer relationships are amortized to depreciation and amortization expense based on the expected discounted future net cash flows by year.

•Marketing partnerships — These intangibles represent the fair value at the acquisition date of existing agreements with marketing vendors and loyalty and affinity partners for customer acquisition. Marketing partnerships are amortized to depreciation and amortization expense based on the expected discounted future net cash flows by year.

•Technology — These intangibles represent the fair value at the acquisition date of developed technology for Vivint Smart Home integrated software and products. Technology is amortized to depreciation and amortization expense, ratably based on the expected discounted future net cash flows by year.

•Trade names — These intangibles are amortized to depreciation and amortization expense on a straight-line basis.

•Other — These intangibles primarily include renewable energy credits. RECs are retired, as required, for the applicable compliance period. RECs are expensed to cost of operations based on NRG’s customer usage. Other also included in-market nuclear fuel contracts established from the Texas Genco acquisition in 2006 which were amortized to cost of operations over expected volumes over the life of each contract, costs to extend the operating license for STP Units 1 and 2 and intellectual property related to Goal Zero, which is amortized to depreciation and amortization expense.

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The following tables summarize the components of NRG's intangible assets:

(In millions)
Year Ended December 31, 2023	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Technology		Trade Names		Other(a)		Total
January 1, 2023	$	624	$	635	$	1,730	$	284	$	—	$	679	$	292	$	4,244
Purchases	10		—		—		—		—		—		465		475
Acquisition of businesses(b)	—		—		1,773		10		860		160		—		2,803
Usage/Sales/Retirements	—		—		—		—		—		—		(474)		(474)
Write-off of fully amortized balances	(1)		(28)		(43)		—		—		—		—		(72)
Sale of STP(c)	—		—		—		—		—		—		(59)		(59)
Other	(5)		2		4		1		—		2		—		4
December 31, 2023	628		609		3,464		295		860		841		224		6,921
Less accumulated amortization	(533)		(328)		(1,300)		(170)		(230)		(401)		(32)		(2,994)
Net carrying amount	$	95	$	281	$	2,164	$	125	$	630	$	440	$	192	$	3,927

(a)RECs are not subject to amortization and had a carrying value of $177 million

(b)The weighted average amortization period for total amortizable intangible assets is approximately 10 years. See Note 4, Acquisitions and Dispositions, for weighted average life of acquired amortizable intangibles for each intangible asset type

(c)Includes $47 million of intangibles that were amortized

(In millions)
Year Ended December 31, 2022	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other(a)		Total
January 1, 2022	$	634	$	638	$	1,679	$	284	$	683	$	229	$	4,147
Purchases	26		—		—		—		—		404		430
Acquisition of businesses(b)	—		—		55		—		—		—		55
Usage/Retirements	(33)		—		—		—		—		(341)		(374)
Write-off of fully amortized balances	(14)		—		—		—		—		—		(14)
Other	11		(3)		(4)		—		(4)		—		—
December 31, 2022	624		635		1,730		284		679		292		4,244
Less accumulated amortization	(528)		(235)		(787)		(146)		(341)		(75)		(2,112)
Net carrying amount	$	96	$	400	$	943	$	138	$	338	$	217	$	2,132

(a)RECs are not subject to amortization and had a carrying value of $186 million

(b)The weighted average life of acquired amortizable intangibles was six years for customer relationships

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The following table presents NRG's amortization of intangible assets for each of the past three years:

	Years Ended December 31,
(In millions)	2023		2022		2021
Emission allowances	$	6	$	6	$	24
Customer and supply contracts	121		141		66
Customer relationships	556		269		327
Marketing partnerships	24		23		24
Technology	230		—		—
Trade names	60		47		47
Other(a)	4		4		7
Total amortization	$	1,001	$	490	$	495

(a)For the year ended December 31, 2023, 2022 and 2021, other intangibles amortized to depreciation and amortization expense were de minimis, $4 million and $3 million, respectively

The following table presents estimated amortization of NRG's intangible assets as of December 31, 2023 for each of the next five years:

(In millions)
Year Ended December 31,	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Technology		Trade Names		Other		Total
2024	$	17	$	73	$	478	$	24	$	227	$	54	$	3	$	876
2025	14		50		371		23		176		47		3		684
2026	9		52		300		23		130		39		3		556
2027	8		30		233		23		89		39		3		425
2028	9		13		189		15		9		39		2		276

Intangible assets held-for-sale — From time to time, management may authorize the transfer from the Company's emission bank of emission allowances held-for-use to intangible assets held-for-sale. Emission allowances held-for-sale are included in other non-current assets on the Company's consolidated balance sheet and are not amortized, but rather expensed as sold. As of December 31, 2023 and 2022, the value of emission allowances held-for-sale was $4 million and $8 million, respectively, within the Corporate segment. Once transferred to held-for-sale, these emission allowances are prohibited from moving back to held-for-use.

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Note 13 — Long-term Debt and Finance Leases

Long-term debt and finance leases consisted of the following:

	As of December 31,
(In millions, except rates)	2023		2022		Interest rate %
Recourse debt:
Senior Notes, due 2027	$	375	$	375	6.625
Senior Notes, due 2028	821		821		5.750
Senior Notes, due 2029	733		733		5.250
Senior Notes, due 2029	500		500		3.375
Senior Notes, due 2031	1,030		1,030		3.625
Senior Notes, due 2032	480		1,100		3.875
Convertible Senior Notes, due 2048(a)	575		575		2.750
Senior Secured First Lien Notes, due 2024	600		600		3.750
Senior Secured First Lien Notes, due 2025	500		500		2.000
Senior Secured First Lien Notes, due 2027	900		900		2.450
Senior Secured First Lien Notes, due 2029	500		500		4.450
Senior Secured First Lien Notes, due 2033	740		—		7.000
Tax-exempt bonds	466		466		1.250 - 4.750
Subtotal recourse debt	8,220		8,100
Non-recourse debt:
Vivint Smart Home Senior Notes, due 2029	800		—		5.750
Vivint Smart Home Senior Secured Notes, due 2027	600		—		6.750
Vivint Smart Home Senior Secured Term Loan, due 2028	1,320		—		SOFR + 3.51
Subtotal all non-recourse debt	2,720		—
Subtotal long-term debt (including current maturities)	10,940		8,100
Finance leases	19		11		various
Subtotal long-term debt and finance leases (including current maturities)	10,959		8,111
Less current maturities	(620)		(63)
Less debt issuance costs	(60)		(70)
Discounts	(146)		(2)
Total long-term debt and finance leases	$	10,133	$	7,976

(a)As of the ex-dividend date of January 31, 2024, the Convertible Senior Notes were convertible at a price of $41.53, which is equivalent to a conversion rate of approximately 24.0763 shares of common stock per $1,000 principal amount

Debt includes the following discounts:

	As of December 31,
(In millions)	2023		2022
Senior Secured First Lien Notes, due 2024, 2025, 2027, 2029 and 2033	$	(10)	$	(2)
Vivint Smart Home Senior Notes, due 2029	(103)		—
Vivint Smart Home Senior Secured Notes, due 2027	(12)		—
Vivint Smart Home Senior Secured Term Loan, due 2028	(21)		—
Total discounts	$	(146)	$	(2)

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Consolidated Annual Maturities

As of December 31, 2023, annual payments based on the maturities of NRG's debt and finance leases are expected to be as follows:

	(In millions)
2024	$	620
2025	769
2026	16
2027	1,890
2028	2,145
Thereafter	5,519
Total	$	10,959

Recourse Debt

Revolving Credit Facility

On February 14, 2023 (the “Revolving Credit Facility Sixth Amendment Effective Date”), the Company amended its Revolving Credit Facility to: (i) increase the existing revolving commitments thereunder by $600 million (the “Initial Incremental Commitment”), (ii) extend the maturity date of a portion of the revolving commitments thereunder to February 14, 2028, (iii) transition the benchmark rate applicable to revolving loans from LIBOR to SOFR and (iv) make certain other amendments to the terms of the Revolving Credit Facility for purposes of, among other things, providing additional flexibility.

On March 13, 2023 (the “Revolving Credit Facility Seventh Amendment Effective Date”), the Company further amended its Revolving Credit Facility to increase the existing revolving commitments by an additional $45 million (together with the Initial Incremental Commitment, the "Incremental Commitment").

After giving effect to the Incremental Commitment, the Company had a total of $4.305 billion of revolving commitments available under the Revolving Credit Facility. The full amount of the Initial Incremental Commitment was made available from and after the Revolving Credit Facility Sixth Amendment Effective Date and the full amount of the Incremental Commitment was made available from and after the Revolving Credit Facility Seventh Amendment Effective Date. A portion of the non-extended revolving commitments terminated on July 5, 2023, with the remaining portion thereof terminating on May 28, 2024, unless otherwise extended.

The Revolving Credit Facility is guaranteed by NRG’s existing and future direct and indirect subsidiaries, with customary and agreed-upon exceptions for, among other exceptions, unrestricted subsidiaries, foreign subsidiaries, project subsidiaries, immaterial subsidiaries, captive insurance subsidiaries and securitization vehicles. The Revolving Credit Facility is also secured by a first priority (subject to certain customary permitted liens) perfected security interest in a substantial portion of the property and assets owned by NRG and its subsidiaries that are guarantors under the Revolving Credit Facility, subject to certain exceptions that include, among other things, the capital stock of certain specified subsidiaries, including unrestricted subsidiaries and certain excluded subsidiaries, equity interests in excess of 66% of the total outstanding voting equity interests of certain foreign subsidiaries, equity interests the pledge of which is prohibited by applicable agreements binding on such subsidiaries and other assets that may be designated by NRG as excluded from the collateral that, when taken together with all other assets so designated since the Revolving Credit Facility Sixth Amendment Effective Date, have an aggregate fair market value not exceeding $750 million. The Revolving Credit Facility is secured on a pari passu basis with certain interest rate, foreign currency and commodity hedging obligations of NRG, the Senior Secured First Lien Notes and certain other indebtedness. The collateral securing the Revolving Credit Facility will be released at the Company's request if both the senior unsecured long-term debt securities of the Company and the revolving loans under the Revolving Credit Facility are rated investment grade by any two of the three rating agencies and the satisfaction of certain other conditions, subject to reversion if such rating agencies withdraw such investment grade rating or downgrade such rating below investment grade (or, with respect to the revolving loans, crease to publish a rating).

The Revolving Credit Facility contains customary covenants, which, among other things, require NRG to maintain a maximum first lien leverage ratio on a consolidated basis when amounts outstanding under the Revolving Credit Facility (subject to certain exceptions) exceed a certain threshold and limit, subject to certain exceptions, NRG’s ability to:

•incur indebtedness and liens and enter into sale and lease-back transactions;

•make investments, loans and advances;

•return capital to shareholders;

•repay material subordinated indebtedness;

•consummate mergers, consolidations and asset sales;

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•enter into affiliate transactions; and

•change its fiscal year-end.

As of December 31, 2023, there were no outstanding borrowings and there were $883 million in letters of credit issued under the Revolving Credit Facility.

Senior Notes

Issuance of 2033 Senior Secured First Lien Notes

On March 9, 2023, the Company issued $740 million of aggregate principal amount of 7.000% senior secured first lien notes due 2033 (the "2033 Senior Secured First Lien Notes"). The 2033 Senior Secured First Lien Notes are senior secured obligations of NRG and are guaranteed by certain of its subsidiaries that guarantee indebtedness under the Revolving Credit Facility. The 2033 Senior Secured First Lien Notes are secured by a first priority security interest in the same collateral that is pledged for the benefit of the lenders under the Revolving Credit Facility, which collateral consists of a substantial portion of the property and assets owned by the Company and the guarantors. The collateral securing the 2033 Senior Secured First Lien Notes will be released at the Company’s request if the senior unsecured long-term debt securities of the Company are rated investment grade by any two of the three rating agencies and the satisfaction of certain other conditions, subject to reversion if such rating agencies withdraw such investment grade rating or downgrade such rating below investment grade. Interest is paid semi-annually beginning on September 15, 2023 until the maturity date of March 15, 2033. The proceeds of the 2033 Senior Secured First Lien Notes, along with cash on hand and proceeds from certain other financings, were used to fund the acquisition of Vivint Smart Home.

Senior Note Redemptions

During the year ended December 31, 2023, the Company redeemed $620 million in aggregate principal amount of its 3.875% Senior Notes, due 2032, for $509 million, which included the payment of $7 million of accrued interest, using cash on hand at an average early redemption percentage of 81%. In connection with the redemption, a $109 million gain on debt extinguishment was recorded, which included the write-off of previously deferred financing costs and other fees of $9 million.

During the year ended December 31, 2021, the Company redeemed approximately $1.9 billion in aggregate principal amount of its Senior Notes for $1.9 billion using the proceeds of the 2032 Senior Notes and cash on hand, as detailed in the table below. In connection with the redemptions, a $77 million loss on debt extinguishment was recorded, which included the write-off of previously deferred financing costs of $12 million.

(In millions, except percentages)	Principal Repurchased		Cash Paid(a)		Average Early Redemption Percentage
7.250% Senior Notes, due 2026	$	1,000	$	1,056	103.625	%
6.625% Senior Notes, due 2027	855		893		103.313	%
Total	$	1,855	$	1,949

(a)Includes accrued interest of $29 million for redemptions for the year ended December 31, 2021

2048 Convertible Senior Notes

Accounting for Convertible Senior Notes — Upon issuance in 2018, the Convertible Senior Notes were separated into liability and equity components for accounting purposes. The carrying amount of the liability component was initially calculated by measuring the fair value of similar liabilities that do not have an associated convertible feature. The carrying amount of the equity component representing the conversion option was determined by deducting the fair value of the liability component from the par value of the Convertible Senior Notes. This difference represented the debt discount that was amortized to interest expense over seven years, which was determined to be the expected life of the Convertible Senior Notes, using the effective interest rate method. The equity component was recorded in additional paid-in capital and was not remeasured as it continued to meet the conditions for equity classification.

Following the adoption of ASU 2020-06 as of January 1, 2022, the Company no longer records the conversion feature of its convertible senior notes in equity. Instead, the Company combined the previously separated equity component with the liability component, which together is now classified as debt, thereby eliminating the subsequent amortization of the debt discount as interest expense. As a result of the provisions of the amended guidance, the Company recorded a $100 million decrease to additional paid-in capital, a $57 million decrease to debt discount, a $57 million increase to retained earnings, and a $14 million decrease to long-term deferred tax liabilities.

Modification to Convertible Senior Notes — On February 22, 2022, the Company irrevocably elected to eliminate the right to settle conversions only in shares of the Company's common stock, such that any conversion after such date, the Company will pay cash per $1,000 principal amount and will settle in cash or a combination of cash and the Company's common stock for the remainder, if any, of the Company’s conversion obligation in excess of the aggregate principal amount.

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Convertible Senior Notes Features — As of December 31, 2023, the Convertible Senior Notes were convertible, under certain circumstances, into cash or a combination of cash and the Company’s common stock at a price of $41.83 per common share, which is equivalent to a conversion rate of approximately 23.9079 shares of common stock per $1,000 principal amount of Convertible Senior Notes. As of December 31, 2022, the Convertible Senior Notes were convertible at a price of $43.46 per common share, which is equivalent to a conversion rate of approximately 23.0116 shares of common stock per $1,000 principal amount of Convertible Senior Notes. The net carrying amounts of the Convertible Senior Notes as of December 31, 2023 and December 31, 2022 were $572 million and $570 million, respectively. The Convertible Senior Notes mature on June 1, 2048, unless earlier repurchased, redeemed or converted in accordance with their terms. The Convertible Senior Notes are convertible at the option of the holders under certain circumstances. Prior to the close of business on the business day immediately preceding December 1, 2024, the Convertible Senior Notes will be convertible only upon the occurrence of certain events and during certain periods, including, among others, during any calendar quarter (and only during such calendar quarter) if the last reported sales price per share of the Company's common stock exceeds 130% of the conversion price for each of at least 20 trading days, whether or not consecutive, during the 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter. Thereafter during specified periods as follows:

•from December 1, 2024 until the close of business on the second scheduled trading day immediately before June 1, 2025; and

•from December 1, 2047 until the close of business on the second scheduled trading day immediately before the maturity date

All conversions with a conversion date that occurs within the specific periods above will be settled after such period pursuant to the terms of the indenture. The following table details the interest expense recorded in connection with the Convertible Senior Notes, due 2048:

	For the years ended December 31,
($ In millions)	2023			2022			2021
Contractual interest expense	$	16		$	16		$	16
Amortization of discount and deferred finance costs(a)	2			1			15
Total	$	18		$	17		$	31
Effective Interest Rate	3.18		%	3.01		%	5.34		%

(a)Upon adoption of ASU 2020-06 on January 1, 2022, which resulted in the removal of the debt discount, no further debt discount amortization is being recorded

Senior Notes Early Redemption

As of December 31, 2023, NRG had the following outstanding issuances of senior notes with an early redemption feature, or Senior Notes:

i.6.625% senior notes, issued August 2, 2016 and due January 15, 2027, or the 2027 Senior Notes;

ii.5.750% senior notes, issued December 7, 2017 and due January 15, 2028, or the 2028 Senior Notes;

iii.5.250% senior notes, issued May 24, 2019 and due June 15, 2029, or the 2029 Senior Notes;

iv.3.375% senior notes, issued December 2, 2020 and due February 15, 2029, or the 3.375% 2029 Senior Notes;

v.3.625% senior notes, issued December 2, 2020 and due February 15, 2031, or the 2031 Senior Notes; and

vi.3.875% senior notes, issued August 23, 2021 and due February 15, 2032, or the 2032 Senior Notes.

The indentures and the forms of notes provide, among other things, that the Senior Notes will be senior unsecured obligations of the Company. The indentures also provide for customary events of default, which include, among others: nonpayment of principal or interest; breach of other agreements in the indentures; defaults in failure to pay certain other indebtedness; the rendering of judgments to pay certain amounts of money against the Company and its subsidiaries; the failure of certain guarantees to be enforceable; and certain events of bankruptcy or insolvency. Generally, if an event of default occurs, the trustee or the holders of at least 25% or 30% (depending on the series of Senior Notes) in principal amount of the then outstanding series of Senior Notes may declare all of the Senior Notes of such series to be due and payable immediately. The terms of the indentures, among other things, limit the Company's ability and certain of its subsidiaries' ability to return capital to stockholders, grant liens on assets to lenders and incur additional debt. Interest is payable semi-annually on the Senior Notes until their maturity dates.

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2027 Senior Notes

The Company may redeem some or all of the 2027 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
July 15, 2023 to July 14, 2024	101.104	%
July 15, 2024 and thereafter	100.000	%

2028 Senior Notes

The Company may redeem some or all of the 2028 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
January 15, 2024 to January 14, 2025	101.917	%
January 15, 2025 to January 14, 2026	100.958	%
January 15, 2026 and thereafter	100.000	%

5.250% 2029 Senior Notes

At any time prior to June 15, 2024, the Company may redeem all or a part of the 5.250% 2029 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the notes; or (ii) the excess of the principal amount of the note over the following: the present value of 102.625% of the note, plus interest payments due on the note through June 15, 2024 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the principal amount of the note. In addition, on or after June 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
June 15, 2024 to June 14, 2025	102.625	%
June 15, 2025 to June 14, 2026	101.750	%
June 15, 2026 to June 14, 2027	100.875	%
June 15, 2027 and thereafter	100.000	%

3.375% 2029 Senior Notes

On or after February 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 to February 14, 2026	100.844	%
February 15, 2026 and thereafter	100.000	%

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2031 Senior Notes

At any time prior to February 15, 2026, the Company may redeem all or a part of the 2031 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the note; or (ii) the excess of the present value of 101.813% of the note, plus interest payments due on the note through February 15, 2026 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the principal amount of the note. In addition, on or after February 15, 2026, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2026 to February 14, 2027	101.813	%
February 15, 2027 to February 14, 2028	101.208	%
February 15, 2028 to February 14, 2029	100.604	%
February 15, 2029 and thereafter	100.000	%

2032 Senior Notes

At any time prior to August 15, 2024, the Company may redeem up to 40% of the aggregate principal amount of the 2032 Senior Notes, at a redemption price equal to 103.875% of the principal amount of the notes redeemed, plus accrued and unpaid interest, with an amount equal to the net cash proceeds of certain equity offerings, provided that at least 50% of the aggregate principal amount remains outstanding immediately after the occurrence of such redemption. At any time prior to February 15, 2027, the Company may redeem all or a part of the 2032 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the notes; or (ii) the excess of (A) the present value of (1) the redemption price of the note at February 15, 2027 (such redemption price being set forth in the table appearing below in the column “Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)” unless the Sustainability Performance Target has been satisfied in respect of the year ended December 31, 2025 and the Company has provided confirmation thereof to the trustee together with a related confirmation by the External Verifier by the date that is at least 15 days prior to August 15, 2026 in which case the redemption price shall be as set forth in the column “Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)”) plus (2) interest payments due on the note through February 15, 2027 (excluding accrued but unpaid interest to the redemption date) computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50%, over (B) the principal amount of the note. In addition, on or after February 15, 2027, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table during the twelve-month period beginning on February 15 of the years indicated below, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Year	Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)		Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)
2027	101.938	%	102.188	%
2028	101.292	%	101.458	%
2029	100.646	%	100.729	%
2030 and thereafter	100.000	%	100.000	%

Receivables Facility

In 2020, NRG Receivables LLC, a bankruptcy remote, special purpose, indirect wholly owned subsidiary, ("NRG Receivables") entered into the Receivables Facility, subject to adjustments on a seasonal basis, with issuers of asset-backed commercial paper and commercial banks (the "Lenders"). The assets of NRG Receivables are first available to satisfy the claims of the Lenders before making payments on the subordinated note and equity issued by NRG Receivables. The assets of NRG Receivables are not available to the Company and its subsidiaries or creditors unless and until distributed by NRG Receivables. Under the Receivables Facility, certain indirect subsidiaries of the Company sell their accounts receivables to NRG Receivables, subject to certain terms and conditions. In turn, NRG Receivables grants a security interest in the purchased receivables to the Lenders as collateral for cash borrowings and issuances of letters of credit. Pursuant to the Performance Guaranty, the Company has guaranteed, for the benefit of NRG Receivables and the Lenders, the payment and performance by each indirect subsidiary of its respective obligations under the Receivables Facility. The accounts receivables remain on the

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Company's consolidated balance sheet and any amounts funded by the Lenders to NRG Receivables will be reflected as short-term borrowings. Cash flows from the Receivables Facility are reflected as financing activities in the Company's consolidated statements of cash flows. The Company continues to service the accounts receivables sold in exchange for a servicing fee.

On June 22, 2023, NRG Receivables amended its existing Receivables Facility to, among other things, (i) extend the scheduled termination date to June 21, 2024, (ii) increase the aggregate commitments from $1.0 billion to $1.4 billion (adjusted seasonally) and (iii) add a new originator. On October 6, 2023, the Receivables Facility was further amended to replace the benchmark interest rate of the Receivable Facility's subordinated note from LIBOR to SOFR. The weighted average interest rate related to usage under the Receivables Facility as of December 31, 2023 was 0.841%. As of December 31, 2023, there were no outstanding borrowings and there were $1.0 billion in letters of credit issued under the Receivables Facility.

Repurchase Facility

In 2020, the Company entered into the Repurchase Facility related to the Receivables Facility. Under the Repurchase Facility, the Company can currently borrow up to $150 million, collateralized by a subordinated note issued by NRG Receivables to NRG Retail LLC in favor of the originating entities representing a portion of the balance of receivables sold to NRG Receivables under the Receivables Facility.

In addition, in connection with the amendments to the Receivables Facility, on June 22, 2023, the Company and the originators thereunder renewed the existing uncommitted Repurchase Facility. Such renewal, among other things, extended the maturity date to June 21, 2024 and joined an additional originator to the Repurchase Facility. On October 6, 2023, the Repurchase Facility was further amended to reflect the concurrent amendment to the Receivables Facility's subordinated note. The Repurchase Facility has no commitment fee and borrowings will be drawn at SOFR + 1.55%. As of December 31, 2023, there were no outstanding borrowings under the Repurchase Facility.

Bilateral Letter of Credit Facilities

On May 19, 2023, May 30, 2023 and October 17, 2023 the Company increased the size of its bilateral letter of credit facilities by $25 million, $100 million and $50 million, respectively, to provide additional liquidity and to allow for the issuance of up to $850 million of letters of credit. These facilities are uncommitted. As of December 31, 2023, $671 million was issued under these facilities.

Tax Exempt Bonds

	As of December 31,
(In millions, except rates)	2023		2022		Interest Rate %
NRG Indian River Power 2020, tax exempt bonds, due 2040	$	57	$	57	1.250
NRG Indian River Power 2020, tax exempt bonds, due 2045	190		190		1.250
NRG Dunkirk 2020, tax exempt bonds, due 2042	59		59		4.250
City of Texas City, tax exempt bonds, due 2045	33		33		4.125
Fort Bend County, tax exempt bonds, due 2038	54		54		4.750
Fort Bend County, tax exempt bonds, due 2042	73		73		4.750
Total	$	466	$	466

Dunkirk Bonds

On April 3, 2023, NRG remarketed $59 million in aggregate principal amount of 4.25% tax-exempt refinancing bonds of the Chautauqua County Capital Resource Corporation (the "Dunkirk Bonds"). The Dunkirk Bonds are guaranteed on a first-priority basis by each of NRG's current and future subsidiaries that guarantee indebtedness under the Revolving Credit Facility. The Dunkirk Bonds are secured by a first priority security interest in the same collateral that is pledged for the benefit of the lenders under the Revolving Credit Facility, which consists of a substantial portion of the property and assets owned by NRG and the guarantors. The collateral securing the Dunkirk Bonds will, at the request of NRG, be released if NRG satisfies certain conditions, including receipt of an investment grade rating on its senior, unsecured debt securities from two out of the three rating agencies, subject to reversion if those rating agencies withdraw their investment grade rating of the Dunkirk Bonds or any of NRG's senior, unsecured debt securities or downgrade such ratings below investment grade. The Dunkirk Bonds are subject to mandatory tender and purchase on April 3, 2028 and have a final maturity date of April 1, 2042.

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Pre-Capitalized Trust Securities Facility

On August 29, 2023, the Company entered into a Facility Agreement (as defined below) with Alexander Funding Trust II, a newly-formed Delaware statutory trust (the “Trust”), in connection with the sale by the Trust of $500 million pre-capitalized trust securities redeemable July 31, 2028 (the “P-Caps”). The Trust invested the proceeds from the sale of the P-Caps in a portfolio of principal and interest strips of U.S. Treasury securities (the “Eligible Treasury Assets”). The P-Caps replaced the Company’s existing pre-capitalized trust securities redeemable 2023 issued by Alexander Funding Trust, which matured on November 15, 2023.

In connection with the sale of the P-Caps, the Company and the guarantors named therein entered into a facility agreement, dated August 29, 2023 (the “Facility Agreement”), with the Trust and Deutsche Bank Trust Company Americas, as notes trustee (the “Notes Trustee”). Under the Facility Agreement, the Company has the right, from time to time, to issue to the Trust, and to require the Trust to purchase from the Company, on one or more occasions (the “Issuance Right”), up to $500 million aggregate principal amount of the Company’s 7.467% Senior Secured First Lien Notes due 2028 (the “P-Caps Secured Notes”) in exchange for all or a portion of the Eligible Treasury Assets corresponding to the portion of the Issuance Right under the Facility Agreement being exercised at such time. The Company pays to the Trust a facility fee equal to 3.13427% applied to the unexercised portion of the Issuance Right on a semi-annual basis.

The P-Caps are to be redeemed by the Trust on July 31, 2028 or earlier upon an early redemption of the P-Caps Secured Notes. Following any distribution of P-Caps Secured Notes to the holders of the P-Caps, the Company may similarly redeem such P-Caps Secured Notes, in whole or in part, at the redemption price described in the P-Caps Indenture (as defined below), plus accrued but unpaid interest to, but excluding, the date of redemption. Any P-Caps Secured Notes outstanding and held by the Trust as a result of the exercise of the Issuance Right that remain outstanding will also mature on July 31, 2028.

The Issuance Right will be exercised automatically in full if (i) the Company fails to pay the facility fee when due or any amount due and owing under the trust expense reimbursement agreement or fails to purchase and pay for any Eligible Treasury Assets that are due and not paid on their payment date and such failure is not cured within 30 days or (ii) upon certain bankruptcy events of the Company. The Company will be required to mandatorily exercise the Issuance Right if certain mandatory exercise events occur upon the terms and conditions set forth in the Facility Agreement.

The P-Caps Secured Notes that may be sold to the Trust from time to time will be governed by the base indenture, dated August 29, 2023 (the “Base Indenture”), between the Company and the Notes Trustee, as supplemented by the supplemental indenture, dated August 29, 2023 (the “Supplemental Indenture” and, together with the Base Indenture, the “P-Caps Indenture”), among the Company, the guarantors named therein and the Notes Trustee.

The P-Caps Secured Notes will, if sold to the Trust, be guaranteed on a first-priority basis by each of the Company’s subsidiaries that guarantee indebtedness under the Revolving Credit Facility. The P-Caps Secured Notes will, if sold to the Trust, be secured by a first priority security interest in the same collateral that is pledged for the benefit of the lenders under the Revolving Credit Facility, which consists of a substantial portion of the property and assets owned by the Company and the guarantors. The collateral securing the P-Caps Secured Notes will be released at the Company’s request if the senior unsecured long-term debt securities of the Company are rated investment grade by any two of the three rating agencies, subject to reversion if such rating agencies downgrade such rating below investment grade or withdraw such investment grade rating.

In connection with the issuance of the P-Caps, on August 29, 2023, the Company entered into a letter of credit facility agreement (the “LC Agreement”) with Deutsche Bank Trust Company Americas, as collateral agent (the “Collateral Agent”) and administrative agent, and certain financial institutions (the “LC Issuers”) for the issuance of letters of credit in an aggregate amount not to exceed $485 million. The LC Agreement replaced the Company’s existing letter of credit facility agreement, effective August 29, 2023. In addition, on August 29, 2023, the Trust entered into a pledge and control agreement (the “Pledge Agreement”), among the Company, the Trust and the Collateral Agent, under which the Company and the Trust agreed to grant a security interest over the Eligible Treasury Assets in favor of the Collateral Agent for the benefit of the LC Issuers. Pursuant to the LC Agreement and the Pledge Agreement, the Collateral Agent is entitled to withdraw Eligible Treasury Assets in the amount of any drawn letters of credit issued pursuant to the LC Agreement from the Company's and the Trust’s pledged accounts, following notice to the Company, in the event the Company has failed to reimburse such drawn amounts and the LC Issuers have the right to instruct the Collateral Agent to enforce the pledge over the Eligible Treasury Assets upon the occurrence of any event of default under the LC Agreement.

Non-recourse Debt

The following are descriptions of certain indebtedness of NRG's subsidiaries. All of NRG's non-recourse debt is secured by the assets in the subsidiaries as further described below.

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Acquired Vivint Smart Home Debt

On March 10, 2023, in connection with the Vivint Smart Home acquisition, Vivint Smart Home's indirect wholly owned subsidiary, APX Group, Inc. ("APX"), retained its 6.750% senior secured notes due 2027, 5.750% senior notes due 2029, senior secured term loan credit agreement and senior secured revolving credit facility.

Vivint Smart Home 2027 Senior Secured Notes

Vivint Smart Home has outstanding $600 million aggregate principal amount of 6.750% senior secured notes due 2027 (the "Vivint Smart Home 2027 Senior Secured Notes"). The Vivint Smart Home 2027 Senior Secured Notes are senior secured obligations of APX and are guaranteed by APX Group Holdings, Inc., each of APX's existing and future wholly owned U.S. restricted subsidiaries (subject to customary exclusions and qualifications) and Vivint Smart Home. Interest on the Vivint Smart Home 2027 Senior Secured Notes is paid semi-annually in arrears on February 15 and August 15 until the maturity date of February 15, 2027.

Vivint Smart Home 2029 Senior Notes

Vivint Smart Home has outstanding $800 million aggregate principal amount of 5.750% senior notes due 2029 (the "Vivint Smart Home 2029 Senior Notes"). The Vivint Smart Home 2029 Senior Notes are senior unsecured obligations of APX and are guaranteed by APX Group Holdings, Inc., each of APX's existing and future wholly owned U.S. restricted subsidiaries (subject to customary exclusions and qualifications) and Vivint Smart Home. Interest on the Vivint Smart Home 2029 Senior Notes is paid semi-annually in arrears on January 15 and July 15 until the maturity date of July 15, 2029.

Vivint Smart Home Senior Secured Credit Facilities

The Vivint Smart Home senior secured credit agreement (the “Vivint Smart Home Credit Agreement”) provides for (i) a term loan facility in an initial aggregate principal amount of $1.4 billion (the “Vivint Smart Home Term Loan Facility”, and the loans thereunder, the “Vivint Smart Home Term Loans”) and (ii) a revolving credit facility in an initial aggregate principal amount of $370 million (the “Vivint Smart Home Revolving Credit Facility,” and the loans thereunder, the “Vivint Smart Home Revolving Loans”).

All of APX’s obligations under the Vivint Smart Home Credit Agreement are guaranteed by APX Group Holdings, Inc. and each of APX’s existing and future wholly-owned U.S. restricted subsidiaries (subject to customary exclusions and qualifications). The obligations under the Vivint Smart Home Credit Agreement are secured by a first priority (subject to certain customary permitted liens) perfected security interest in (i) substantially all of the present and future tangible and intangible assets of APX, and the guarantors, including without limitation equipment, subscriber contracts and communication paths, intellectual property, general intangibles, investment property, material intercompany notes and proceeds of the foregoing, subject to permitted liens and other customary exceptions, (ii) substantially all personal property of APX and the guarantors consisting of accounts receivable arising from the sale of inventory and other goods and services (including related contracts and contract rights, inventory, cash, deposit accounts, other bank accounts and securities accounts), inventory and intangible assets to the extent attached to the foregoing books and records of APX and the guarantors, and the proceeds thereof, subject to permitted liens and other customary exceptions, in each case held by APX and the guarantors and (iii) a pledge of all of the capital stock of APX, each of its subsidiary guarantors and each restricted subsidiary of APX and its subsidiary guarantors (subject to customary exclusions and qualifications), in each case other than certain excluded assets and subject to the limitations and exclusions provided in the applicable collateral documents.

The Vivint Smart Home Credit Agreement contains customary covenants, which, among other things, require APX to maintain a maximum first lien net leverage ratio when amounts outstanding under the Vivint Smart Home Revolving Facility exceed a certain threshold and restrict, subject to certain exceptions, APX and its restricted subsidiaries’ ability to:

•incur or guarantee additional debt or issue disqualified stock or preferred stock;

•pay dividends and make other distributions on, or redeem or repurchase, capital stock;

•make certain investments;

•incur certain liens;

•enter into transactions with affiliates;

•merge or consolidate;

•materially change the nature of their business;

•enter into agreements that restrict the ability of restricted subsidiaries to make dividends or other payments to APX or grant liens on their assets;

•designate restricted subsidiaries as unrestricted subsidiaries;

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•amend, prepay, redeem or purchase certain material contractually subordinated debt; and

•transfer or sell certain assets.

On June 9, 2023, Vivint Smart Home entered into an amendment to the Vivint Smart Home Credit Agreement which transitioned the benchmark rate applicable to the Vivint Smart Home Term Loans and the Vivint Smart Home Revolving Loans from LIBOR to SOFR. As of December 31, 2023, the aggregate outstanding principal amount of the Vivint Term Loans was $1.3 billion. As of December 31, 2023, Vivint Smart Home had no outstanding borrowings under the Vivint Smart Home Revolving Credit Facility.

Vivint Smart Home Notes Early Redemption

2027 Senior Secured Notes

APX may redeem some or all of the 2027 Senior Secured Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 and thereafter	100.000	%

2029 Senior Notes

At any time prior to July 15, 2024 and from time to time, APX may redeem the notes in whole or in part, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the note; and (ii) the excess , if any, of (a) the present value at such redemption date of (i) the redemption price of such note at July 15, 2024, plus (ii) interest payments due on the note through July 15, 2024 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the then outstanding principal amount of such note. In addition, on or after July 15, 2024, APX may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
July 15, 2024 to July 14, 2025	102.875	%
July 15, 2025 to July 14, 2026	101.438	%
July 15, 2026 and thereafter	100.100	%

Note 14 — Asset Retirement Obligations

The Company's AROs are primarily related to the environmental obligations for mine reclamation, ash disposal, site closures, fuel storage facilities and future dismantlement of equipment on leased property. In addition, the Company has also identified conditional AROs for asbestos removal and disposal, which are specific to certain power generation operations.

Following the sale of the Company's 44% equity interest in STP on November 1, 2023, the Company no longer has asset retirement obligations related to nuclear decommissioning. Prior to the sale, accretion for the nuclear decommissioning ARO and amortization of the related ARO asset were recorded to the Nuclear Decommissioning Trust Liability and were not included in net income, consistent with regulatory treatment per ASC 980, Regulated Operations.

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The following table represents the balance of ARO obligations as of December 31, 2023 and 2022, along with the activity related to the Company's ARO obligations for the year ended December 31, 2023:

(In millions)	Nuclear Decommission		Other(a)		Total
Balance as of December 31, 2022	$	340	$	418	$	758
Revisions in estimates for current obligations	(13)		3		(10)
Additions	—		13		13
Spending for current obligations	—		(42)		(42)
Accretion	16		23		39
Dispositions	(343)		(8)		(351)
Balance as of December 31, 2023	$	—	$	407	$	407

(a)Total accretion expense related to asset retirement obligations included in the consolidated statement of cash flows includes accretion and revisions in estimates for asset retirement liabilities on non-operating plants

Note 15 — Benefit Plans and Other Postretirement Benefits

NRG sponsors and operates defined benefit pension and other postretirement plans. NRG pension benefits are available to eligible non-union and union employees through various defined benefit pension plans. These benefits are based on pay, service history and age at retirement. Most pension benefits are provided through tax-qualified plans. NRG also provides postretirement health and welfare benefits for certain groups of employees. Cost sharing provisions vary by the terms of any applicable collective bargaining agreements.

NRG maintains three separate qualified pension plans, the NRG Pension Plan for Bargained Employees, the NRG Pension Plan and the Pension Plan for Employees of Direct Energy Marketing Limited ("DEML"). Participation in the NRG Pension Plan for Bargained Employees depends upon whether an employee is covered by a bargaining agreement. The NRG Pension plan was frozen for non-union employees on December 31, 2018. The Pension Plan for Employees of DEML is closed to new participants.

NRG expects to contribute $43 million to the Company's pension plans in 2024, of which $23 million relates to the GenOn plan.

NRG Defined Benefit Plans

The annual net periodic benefit cost/(credit) related to NRG's pension and other postretirement benefit plans include the following components:

	Year Ended December 31,
	Pension Benefits
(In millions)	2023		2022		2021
Service cost benefits earned	$	5	$	7	$	9
Interest cost on benefit obligation	50		41		27
Expected return on plan assets	(39)		(47)		(66)
Amortization of unrecognized net loss	6		3		1
Curtailment and special termination benefits (income)/expense	(1)		14		2
Net periodic benefit cost/(credit)	$	21	$	18	$	(27)

	Year Ended December 31,
	Other Postretirement Benefits
(In millions)	2023		2022		2021
Interest cost on benefit obligation	$	4	$	2	$	2
Amortization of unrecognized prior service cost	(8)		(8)		(10)
Amortization of unrecognized net loss	1		2		1
Curtailment expense	—		—		1
Net periodic benefit credit	$	(3)	$	(4)	$	(6)

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A comparison of the pension benefit obligation, other postretirement benefit obligations and related plan assets for NRG's plans on a combined basis is as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Benefit obligation at January 1	$	1,036	$	1,452	$	84	$	105
Service cost	5		7		—		—
Interest cost	50		41		4		2
Actuarial loss/(gain)	22		(289)		(5)		(11)
Employee and retiree contributions	—		—		4		3
Curtailment and special termination benefit loss	(2)		—		(1)		—
Benefit payments	(89)		(171)		(11)		(15)
Foreign exchange translation	1		(4)		—		—
Benefit obligation at December 31	1,023		1,036		75		84
Fair value of plan assets at January 1	844		1,336		—		—
Actual return on plan assets	93		(317)		—		—
Employee and retiree contributions	—		—		4		3
Employer contributions	2		—		7		12
Benefit payments	(89)		(171)		(11)		(15)
Foreign exchange translation	1		(4)		—		—
Fair value of plan assets at December 31	851		844		—		—
Funded status at December 31 — excess of obligation over assets	$	(172)	$	(192)	$	(75)	$	(84)

During the year ended December 31, 2023, the actuarial loss of $22 million on pension benefits was primarily driven by decreasing discount rates.

During the year ended December 31, 2022, the actuarial gain of $289 million on pension benefits was primarily driven by increasing discount rates.

Amounts recognized in NRG's balance sheets were as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Other current liabilities	$	—	$	—	$	5	$	7
Other non-current liabilities	172		192		70		77

Amounts recognized in NRG's accumulated OCI that have not yet been recognized as components of net periodic benefit cost were as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Net loss/(gain)	$	73	$	110	$	(14)	$	(7)
Prior service cost/(credit)	—		1		(4)		(12)
Total accumulated OCI	$	73	$	111	$	(18)	$	(19)

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Other changes in plan assets and benefit obligations recognized in OCI were as follows:

	Year Ended December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Net actuarial (gain)/loss	$	(31)	$	74	$	(5)	$	(11)
Amortization of net actuarial loss	(6)		(3)		(1)		(2)
Amortization of prior service cost	—		—		8		8
Effect of settlement/curtailment	(1)		(14)		(1)		—
Total recognized in OCI	$	(38)	$	57	$	1	$	(5)
Net periodic benefit cost/(credit)	21		18		(3)		(4)
Net recognized in net periodic pension (credit)/cost and OCI	$	(17)	$	75	$	(2)	$	(9)

The following table presents the balances of significant components of NRG's pension plan:

	As of December 31,
	Pension Benefits
(In millions)	2023		2022
Projected benefit obligation	$	1,023	$	1,036
Accumulated benefit obligation	1,015		1,022
Fair value of plan assets	851		844

NRG's market-related value of its plan assets is the fair value of the assets. The fair values of the Company's pension plan assets by asset category and their level within the fair value hierarchy are as follows:

	Fair Value Measurements as of December 31, 2023
(In millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Total
Common/collective trust investment — U.S. equity	$	—	$	156	$	156
Common/collective trust investment — non-U.S. equity	—		58		58
Common/collective trust investment — non-core assets	—		81		81
Common/collective trust investment — fixed income	—		188		188
Short-term investment fund	19		—		19
Subtotal fair value	$	19	$	483	$	502
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					32
Common/collective trust investment — fixed income					243
Common/collective trust investment — non-core assets					47
Partnerships/joint ventures					27
Total fair value					$	851

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	Fair Value Measurements as of December 31, 2022
(In millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Total
Common/collective trust investment — U.S. equity	$	—	$	155	$	155
Common/collective trust investment — non-U.S. equity	—		65		65
Common/collective trust investment — non-core assets	—		90		90
Common/collective trust investment — fixed income	—		181		181
Short-term investment fund	22		—		22
Subtotal fair value	$	22	$	491	$	513
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					33
Common/collective trust investment — fixed income					220
Common/collective trust investment — non-core assets					55
Partnerships/joint ventures					23
Total fair value					$	844

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 in its entirety. The fair value of the common/collective trust investments is valued at fair value which is equal to the sum of the market value of all of the fund's underlying investments. Certain common/collective trust investments have readily determinable fair value as they publish daily net asset value, or NAV, per share and are categorized as Level 2. Certain other common/collective trust investments and partnerships/joint ventures use NAV per share, or its equivalent, as a practical expedient for valuation, and thus have been removed from the fair value hierarchy table.

The following table presents the significant assumptions used to calculate NRG's benefit obligations:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
Weighted-Average Assumptions	2023		2022		2023		2022
Discount rate	4.97	%	5.18	%	4.96	%	5.19	%
Interest crediting rate	5.67	%	5.21	%	4.66	%	4.00	%
Rate of compensation increase	3.06	%	3.06	%	—		—
Health care trend rate	—		—		7.7% grading to 4.5% in 2033		7% grading to 4.4% in 2031

The following table presents the significant assumptions used to calculate NRG's benefit expense:

	As of December 31,
	Pension Benefits						Other Postretirement Benefits
Weighted-Average Assumptions	2023		2022		2021		2023		2022		2021
Discount rate	5.18	%	2.89%/4.71%/5.41%		2.55	%	5.19	%	2.82	%	2.81	%
Interest crediting rate	5.21	%	3.07	%	3.13	%	4.00	%	1.94	%	1.62	%
Expected return on plan assets	5.55	%	4.99	%	5.62	%	—		—		—
Rate of compensation increase	3.06	%	3.06	%	3.06	%	—		—		—
Health care trend rate	—		—		—		7.2% grading to 4.5% in 2028		6.9% grading to 4.4% in 2028		7.0% grading to 4.4% in 2028

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NRG uses December 31 of each respective year as the measurement date for the Company's pension and other postretirement benefit plans. The Company sets the discount rate assumptions on an annual basis for each of NRG's defined benefit retirement plans as of December 31. The discount rate assumptions represent the current rate at which the associated liabilities could be effectively settled at December 31. The Company utilizes the Aon AA Above Median, or AA-AM, yield curve and the AON Canada yield curve to select the appropriate discount rate assumption for its retirement plans. The AA-AM yield curve is a hypothetical AA yield curve represented by a series of annualized individual spot discount rates from 6 months to 99 years. Under the AA-AM yield curve, each bond issue used to build this yield curve must be non-callable, and have an average rating of AA when averaging available Moody's Investor Services, Standard & Poor's and Fitch ratings. The AON Canada yield curve is based on high quality corporate bonds. Under the AON Canada yield curve, expected plan cash flows were discounted using the yield curve, and then a single rate is determined which produces an equivalent present value.

NRG employs a total return investment approach, whereby a mix of equities and fixed income investments are used to maximize the long-term return of plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan funded status, and corporate financial condition. The Investment Committee reviews the asset mix periodically and as the plan assets increase in future years, the Investment Committee may examine other asset classes such as real estate or private equity. NRG employs a building block approach to determining the long-term rate of return assumption for plan assets, with proper consideration given to diversification and rebalancing. Historical markets are studied and long-term historical relationships between equities and fixed income are preserved, consistent with the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current factors such as inflation and interest rates are evaluated before long-term capital market assumptions are determined. Peer data and historical returns are reviewed to check for reasonableness and appropriateness.

The target allocations of NRG's pension plan assets were as follows for the year ended December 31, 2023:

U.S. equity	19	%
Non-U.S. equity	12	%
Non-core assets	17	%
Fixed Income	52	%

Plan assets are currently invested in a diversified blend of equity and fixed-income investments. Furthermore, equity investments are diversified across U.S., non-U.S., global, and emerging market equities, as well as among growth, value, small and large capitalization stocks.

Investment risk and performance are monitored on an ongoing basis through quarterly portfolio reviews of each asset fund class to a related performance benchmark, if applicable, and annual pension liability measurements. Performance benchmarks are composed of the following indices:

Asset Class	Index
U.S. equities	Dow Jones U.S. Total Stock Market Index
Non-U.S. equities	MSCI All Country World Index
Non-core assets(a)	Various (per underlying asset class)
Fixed income securities	Barclays Short, Intermediate and Long Credits/Barclays Strips 20+ Index and FTSE Canada Universe Bond Index

(a)Non-Core Assets are defined as diversifying asset classes approved by the Investment Committee that are intended to enhance returns and/or reduce volatility of the U.S. and non-U.S. equities. Asset classes considered Non-Core include, but may not be limited to: Emerging Market Equity, Emerging Market Debt, Non-US Developed Market Small Cap, High Yield Fixed Income, Real Estate, Bank Loans, Global Infrastructure and other Alternatives

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NRG's expected future benefit payments for each of the next five years, and in the aggregate for the five years thereafter, are as follows:

	Pension		Other Postretirement Benefit
(In millions)	Benefit Payments		Benefit Payments		Medicare Prescription Drug Reimbursements
2024	$	82	$	5	$	—
2025	81		5		—
2026	79		5		—
2027	78		5		—
2028	76		5		—
2029-2033	360		27		2

STP Defined Benefit Plans

STPNOC, which operates and maintains STP, provides its employees a defined benefit pension plan, as well as postretirement health and welfare benefits. Although NRG did not sponsor the STP plan, it reimbursed STPNOC for 44% of the contributions made towards its retirement plan obligations. For the years ended December 31, 2023 and December 31, 2022, NRG reimbursed STPNOC $3 million and $18 million, respectively, for its contribution to the plans. On November 1, 2023, the Company closed on the sale of its 44% equity interest in STP. Following the sale, the Company is no longer responsible for further reimbursements to the STP pension plan.     

The Company recognized the following in its statement of financial position, statement of operations and accumulated OCI related to its former 44% interest in STP:

	As of December 31,
	Pension Benefits		Other Postretirement Benefits
(In millions)	2022		2022
Funded status — STPNOC benefit plans	$	(7)	$	(13)
Net periodic benefit cost/(credit)	2		(4)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(27)		1

Defined Contribution Plans

NRG's employees are also eligible to participate in defined contribution 401(k) plans.

The Company's costs related to these plans were as follows:

	Year Ended December 31,
(In millions)	2023		2022		2021
Cost recognized for defined contribution plans	$	61	$	37	$	35

The Company's costs, which are primarily related to employer matching of a portion of employee contributions to defined contribution plans, increased during 2023 primarily due to an increase in retirement saving plan match and the Vivint acquisition.

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Note 16 — Capital Structure

For the period from December 31, 2020 to December 31, 2023, the Company had 10,000,000 shares of preferred stock authorized and 500,000,000 shares of common stock authorized. The following table reflects the changes in NRG's preferred and common shares issued and outstanding for each period presented:

	Preferred Shares	Common Shares
	Issued and Outstanding	Issued	Treasury	Outstanding
Balance as of December 31, 2020	—	423,057,848	(178,825,915)	244,231,933
Shares issued under ESPP	—	—	117,392	117,392
Shares issued under LTIPs	—	489,326	—	489,326
Share repurchases	—	—	(1,084,752)	(1,084,752)
Balance as of December 31, 2021	—	423,547,174	(179,793,275)	243,753,899
Shares issued under ESPP	—	—	142,825	142,825
Shares issued under LTIPs	—	349,827	—	349,827
Share repurchases	—	—	(14,685,521)	(14,685,521)
Balance as of December 31, 2022	—	423,897,001	(194,335,971)	229,561,030
Issuance of Series A Preferred Stock	650,000	—	—	—
Shares issued under ESPP	—	—	191,249	191,249
Shares issued under LTIPs	—	1,109,611	—	1,109,611
Share repurchases	—	—	(22,730,940)	(22,730,940)
Retirement of treasury stock	—	(157,676,142)	157,676,142	—
Balance as of December 31, 2023	650,000	267,330,470	(59,199,520)	208,130,950
Shares issued under LTIPs	—	660,267	—	660,267
Share repurchases	—	—	(770,205)	(770,205)
Retirement of treasury stock	—	(770,205)	770,205	—
Balance as of February 1, 2024	650,000	267,220,532	(59,199,520)	208,021,012

Common Stock

As of December 31, 2023, NRG had 27,362,083 shares of common stock reserved for the maximum number of shares potentially issuable based on the conversion and redemption features of the long-term incentive plans.

Common Stock Dividends

The Company declared and paid $0.3775, $0.350 and $0.325 quarterly dividend per common share, or $1.51, $1.40 and $1.30 per share on an annualized basis for 2023, 2022 and 2021 respectively.

In 2021, 2022 and 2023, NRG increased the annual dividend on its common stock to $1.30, $1.40 and $1.51 per share, respectively, representing an 8% increase each year. The long-term capital allocation policy targets an annual dividend growth rate of 7%-9% per share in subsequent years. Beginning in the first quarter of 2024, NRG will increase the annual dividend by 8% to $1.63 per share.

The Company's common stock dividends are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations.

On January 19, 2024, NRG declared a quarterly dividend on the Company's common stock of $0.4075 per share, or $1.63 per share on an annualized basis, payable on February 15, 2024, to stockholders of record as of February 1, 2024.

Employee Stock Purchase Plan 

The Company offers participation in the ESPP which allows eligible employees to elect to withhold between 1% and 10% of their eligible compensation to purchase shares of NRG common stock at the lesser of 90% of its market value on the offering date or 90% of the fair market value on the exercise date. An offering date occurs each April 1 and October 1. An exercise date occurs each September 30 and March 31. On April 27, 2023, NRG stockholders approved the adoption of the Amended and Restated Employee Stock Purchase Plan, effective April 1, 2023, which included a reduction in the price at which eligible employees may purchase shares of NRG common stock from 95% to 90% of the fair market value of the shares on the applicable date. NRG stockholders also approved an increase of 4,400,000 shares available for the issuance under the ESPP. As of December 31, 2023, there remained 6,702,125 shares of treasury stock reserved for issuance under the ESPP.

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Share Repurchases

Share repurchases in 2021 and 2022 were made under the December 6, 2021 $1 billion authorization, as part of NRG’s capital allocation policy. On June 22, 2023, following the acquisition of Vivint Smart Home, NRG revised its long-term capital allocation policy to target allocating approximately 80% of cash available for allocation, after debt reduction, to be returned to shareholders. As part of the revised capital allocation framework, the Company announced an increase to its share repurchase authorization to $2.7 billion, to be executed through 2025.

On November 6, 2023, the Company executed Accelerated Share Repurchase agreements to repurchase a total of $950 million of NRG's outstanding common stock. Under the ASR agreements, the Company paid a total of $950 million and will receive shares of NRG's common stock on specified settlement dates. The total number of shares purchased pursuant to the ASR agreements will generally be based on the volume-weighted average prices of NRG's common stock during the term of each ASR agreement, less a discount. The Company received initial shares of 4,494,224 on November 8, 2023 and an additional 13,181,918 shares on December 27, 2023, which were recorded in treasury stock at fair value based on the volume-weighted average closing prices of $833 million, with the remaining $117 million recorded in additional paid in capital, representing the value of the forward contracts to purchase additional shares. On January 30, 2024, an additional 770,205 shares were delivered. The ASR period will end in March of 2024 and additional shares may be delivered upon final settlement of the remaining agreements. The total number of shares delivered and the average price paid for all of the shares delivered under the ASR agreements will be determined at the end of the ASR period.

During the year ended December 31, 2023, the Company completed $1.2 billion of share repurchases under the $2.7 billion authorization, including $950 million through the ASR and $200 million through open market repurchases at an average price of $39.56. As of February 1, 2024, $1.5 billion is remaining under the $2.7 billion authorization.

The following table summarizes the share repurchases made from 2021 through February 1, 2024:

	Total number of shares purchased	Average price paid per share		Amounts paid for shares purchased (in millions)
2021 Repurchases:
Open market repurchases(a)	1,084,752	$	40.85	$	44
2022 Repurchases:
Open market repurchases	14,685,521	40.48		595
2023 Repurchases:
Open market repurchases	5,054,798			200
Repurchases made under the accelerated share repurchase agreements(b)	17,676,142			950
Total Share Repurchases during 2023	22,730,940	(e)		$	1,150	(c)
Repurchases made subsequent to December 31, 2023 under the accelerated share repurchase agreements(d)	770,205			—
Total Share Repurchases January 1, 2023 through February 1, 2024	23,501,145	(e)		$	1,150

(a)Includes $5 million accrued as of December 31, 2021

(b)Initial and interim shares delivered under the November 6, 2023 accelerated share repurchase agreements

(c)Excludes $10 million accrued for excise tax owed as of December 31, 2023

(d)Additional shares delivered under the November 6, 2023 accelerated share repurchase agreements

(e)The total number of shares delivered and the average price per share under the ASR agreements will be determined at the end of the ASR period

Retirement of Treasury Stock

In the fourth quarter of 2023, the Company retired 157,676,142 shares of treasury stock. These retired shares are now included in NRG's pool of authorized but unissued shares. The retired stock had a carrying value of approximately $5.0 billion. The Company's accounting policy upon the formal retirement of treasury stock is to deduct its par value from common stock and to reflect any excess of cost over par value as a deduction from additional paid-in capital.

Preferred Stock

Series A Preferred Stock

On March 9, 2023 ("Series A Issuance Date"), the Company issued 650,000 shares of 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock. The net proceeds of $635 million, net of issuance costs, were used to partially fund the Vivint Smart Home acquisition.

The Series A Preferred Stock is not convertible into or exchangeable for any other securities or property and has limited voting rights. The Series A Preferred Stock may be redeemed, in whole or in part, on one or more occasions, at the option of the

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Company at any time after March 15, 2028 ("Series A First Reset Date") and in certain other circumstances prior to the Series A First Reset Date. The Series A Preferred Stock has a liquidation preference of $1,000 per share, plus accumulated but unpaid dividends.

Series A Preferred Stock Dividends

The annual dividend rate on each share of Series A Preferred Stock is 10.25% from the Series A Issuance Date to, but excluding the Series A First Reset Date. On and after the Series A First Reset Date, the dividend rate on each share of Series A Preferred Stock shall equal the five-year U.S. Treasury rate as of the most recent reset dividend determination date (subject to a floor of 1.00%), plus a spread of 5.92% per annum. Cumulative cash dividends on the Series A Preferred Stock are payable semiannually, in arrears, on each March 15 and September 15, when, as and if declared by the Board of Directors. In September 2023, the Company declared and paid a semi-annual dividend of $52.96 per share on its outstanding Series A Preferred Stock, totaling $34 million.

Note 17 — Investments Accounted for by the Equity Method and Variable Interest Entities

Entities that are not Consolidated

NRG accounts for the Company's significant investments using the equity method of accounting. NRG's carrying value of equity investments can be impacted by a number of elements including impairments and movements in foreign currency exchange rates.

The following table summarizes NRG's equity method investments as of December 31, 2023:

(In millions, except percentages)
Name:	Economic Interest		Investment Balance
Gladstone	37.5	%	$	34
Midway-Sunset Cogeneration Company	50.0	%	8
Total equity investments in affiliates			$	42

The following table summarizes the undistributed earnings from NRG's equity method investments as of December 31, 2023:

	As of December 31,
(In millions)	2023		2022
Undistributed earnings	$	—	$	42

Other Equity Investments

Gladstone — Through a joint venture, NRG owns a 37.5% interest in Gladstone, a 1,613 MW coal-fueled power generation facility in Queensland, Australia. The power generation facility is managed by the joint venture participants and the facility is operated by NRG. Operating expenses incurred in connection with the operation of the facility are funded by each of the participants in proportion to their ownership interests. Coal is sourced from local mines in Queensland. NRG and the joint venture participants receive their respective share of revenues directly from the off takers in proportion to the ownership interests in the joint venture. Power generated by the facility is primarily sold to an adjacent aluminum smelter, with excess power sold to the Queensland Government-owned utility under long-term supply contracts. NRG's investment in Gladstone was $34 million as of December 31, 2023.

Entities that are Consolidated

The Company has a controlling financial interest that has been identified as a VIE under ASC 810 in NRG Receivables LLC, which has entered into financing transactions related to the Receivables Facility as further described in Note 13, Long-term Debt and Finance Leases.

The summarized financial information for the Company's consolidated VIEs consisted of the following:

(In millions)	December 31, 2023		December 31, 2022
Accounts receivable and Other current assets	$	1,541	$	2,108
Current liabilities	153		152
Net assets	$	1,388	$	1,956

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Note 18 — (Loss)/Income Per Share

Basic (loss)/income per common share is computed by dividing net (loss)/income less cumulative dividends attributable to preferred stock by the weighted average number of common shares outstanding. Shares issued and treasury shares repurchased during the year are weighted for the portion of the year that they were outstanding. Diluted (loss)/income per share is computed in a manner consistent with that of basic (loss)/income per share, while giving effect to all potentially dilutive common shares that were outstanding during the period.

Dilutive effect for equity compensation and other equity instruments — The relative performance stock units, non-vested restricted stock units, market stock units and non-qualified stock options are not considered outstanding for purposes of computing basic (loss)/income per share. However, these instruments are included in the denominator for purposes of computing diluted (loss)/income per share under the treasury stock method for periods when there is net income. The Convertible Senior Notes are convertible, under certain circumstances, into cash or combination of cash and Company’s common stock. Prior to adoption of ASU 2020-06, there was no dilutive effect for the Convertible Senior Notes due to the Company’s expectation to settle the liability in cash. Upon adoption of ASU 2020-06, on January 1, 2022, the Company is including the potential share settlements, if any, in the denominator for purposes of computing diluted (loss)/income per share under the if converted method for periods when there is net income. The potential shares settlements are calculated as the excess of the Company's conversion obligation over the aggregate principal amount (which will be settled in cash), divided by the average share price for the period. For the year ended December 31, 2023, there was no dilutive effect for the Convertible Senior Note since there was a net loss. For the year ended December 31, 2022, there was no dilutive effect for the Convertible Senior Notes since there were no potential share settlements for the period.

The reconciliation of NRG's basic and diluted (loss)/income per share is shown in the following table:

	Year Ended December 31,
(In millions, except per share amounts)	2023		2022		2021
Basic and diluted (loss)/income per share:
Net (loss)/income	$	(202)	$	1,221	$	2,187
Less: Cumulative dividends attributable to Series A Preferred Stock	54		—		—
(Loss)/Income Available to Common Stockholders	$	(256)	$	1,221	$	2,187
Weighted average number of common shares outstanding - basic and diluted	228		236		245
(Loss)/Income per weighted average common share — basic and diluted	$	(1.12)	$	5.17	$	8.93

As of December 31, 2023, the Company had 6 million of outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted loss per share. As of December 31, 2022 and 2021, the Company had an insignificant number of outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company’s diluted income per share.

Note 19 — Segment Reporting

The Company’s segment structure reflects how management makes financial decisions and allocates resources. The Company manages its operations based on the combined results of the retail and wholesale generation businesses with a geographical focus. Vivint Smart Home operations are reported within the Vivint Smart Home segment.

NRG's chief operating decision maker, its interim 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, free cash flow and allocation of capital, as well as net income/(loss). The accounting policies of the segments are the same as those applied in the consolidated financial statements as disclosed in Note 2, Summary of Significant Accounting Policies.

The Company had no customer that comprised more than 10% of the Company's consolidated revenues during the years ended December 31, 2023, 2022 and 2021.

Intersegment sales are accounted for at market.

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	For the Year Ended December 31, 2023
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate(b)		Eliminations		Total
Revenue(b)	$	10,476	$	12,547	$	4,281	$	1,549	$	—	$	(30)	$	28,823
Operating expenses	8,407		14,412		5,025		917		133		(30)		28,864
Depreciation and amortization	294		116		95		586		36		—		1,127
Impairment losses	2		4		20		—		—		—		26
Total operating cost and expenses	8,703		14,532		5,140		1,503		169		(30)		30,017
Gain on sale of assets	1,319		259		—		—		—		—		1,578
Operating income/(loss)	3,092		(1,726)		(859)		46		(169)		—		384
Equity in earnings of unconsolidated affiliates	—		—		16		—		—		—		16
Impairment losses on investments	—		—		(102)		—		—		—		(102)
Other income, net	2		11		6		(12)		56		(16)		47
Gain on debt extinguishment	—		—		—		—		109		—		109
Interest expense	(3)		(3)		(31)		(177)		(469)		16		(667)
Income/(loss) before income taxes	3,091		(1,718)		(970)		(143)		(473)		—		(213)
Income tax (benefit)/expense(c)	—		—		(111)		(32)		132		—		(11)
Net income/(loss)	$	3,091	$	(1,718)	$	(859)	$	(111)	$	(605)	$	—	$	(202)
Balance sheet
Equity investments in affiliates	$	—	$	—	$	42	$	—	$	—	$	—	$	42
Capital expenditures	495		5		27		18		53		—		598
Goodwill	643		721		221		3,494		—		—		5,079
Total assets	$	8,236	$	13,712	$	3,626	$	7,043	$	19,919	$	(26,498)	$	26,038

(a) Includes results of operations following the acquisition date of March 10, 2023
(b) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	5	$	9	$	16	$	—	$	—	$	—	$	30
(c) Consolidated domestic federal and state income taxes are recorded to the Corporate segment, except for Vivint Smart Home which is recorded directly to the Vivint Smart Home segment. West/Services/Other amounts represent foreign income taxes

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	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenue(a)	$	10,057	$	16,763	$	4,706	$	—	$	17	$	31,543
Operating expenses	8,495		16,031		4,108		86		17		28,737
Depreciation and amortization	310		208		85		31		—		634
Impairment losses	—		206		—		—		—		206
Total operating cost and expenses	8,805		16,445		4,193		117		17		29,577
Gain/(loss) on sale of assets	10		—		45		(3)		—		52
Operating income/(loss)	1,262		318		558		(120)		—		2,018
Equity in (losses)/earnings of unconsolidated affiliates	(2)		—		8		—		—		6
Other income, net	5		10		3		54		(16)		56
Interest expense	—		(1)		(32)		(400)		16		(417)
Income/(loss) before income taxes	1,265		327		537		(466)		—		1,663
Income tax expense(b)	—		1		57		384		—		442
Net income/(loss)	$	1,265	$	326	$	480	$	(850)	$	—	$	1,221
Balance sheet
Equity investments in affiliates	$	—	$	—	$	133	$	—	$	—	$	133
Capital expenditures	273		7		37		50		—		367
Goodwill	710		723		217		—		—		1,650
Total assets	$	11,475	$	19,526	$	8,139	$	35,780	$	(45,774)	$	29,146

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	4	$	(26)	$	5	$	—	$	—	$	(17)
(b) Consolidated domestic federal and state income taxes are recorded to the Corporate segment. West/Services/Other amounts represent foreign income taxes

	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenue(a)	$	10,295	$	13,025	$	3,659	$	—	$	10	$	26,989
Operating expenses	8,692		10,256		3,467		141		10		22,566
Depreciation and amortization	336		333		88		28		—		785
Impairment losses	—		535		9		—		—		544
Total operating cost and expenses	9,028		11,124		3,564		169		10		23,895
Gain on sale of assets	19		—		17		211		—		247
Operating income	1,286		1,901		112		42		—		3,341
Equity in (losses)/earnings of unconsolidated affiliates	(3)		—		20		—		—		17
Other income, net	8		7		3		59		(14)		63
Loss on debt extinguishment	—		—		—		(77)		—		(77)
Interest expense	(1)		(1)		(28)		(469)		14		(485)
Income/(loss) before income taxes	1,290		1,907		107		(445)		—		2,859
Income tax expense(b)	—		—		19		653		—		672
Net income/(loss)	$	1,290	$	1,907	$	88	$	(1,098)	$	—	$	2,187

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	5	$	(18)	$	3	$	—	$	—	$	(10)
(b) Consolidated domestic federal and state income taxes are recorded to the Corporate segment. West/Services/Other amounts represent foreign income taxes

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Note 20 — Income Taxes

The income tax provision consisted of the following amounts:

	Year Ended December 31,
(In millions, except effective income tax rate)	2023			2022			2021
Current
U.S. Federal	$	26		$	3		$	—
State	84			65			48
Foreign	(12)			3			3
Total — current	98			71			51
Deferred
U.S. Federal	50			258			569
State	(61)			59			36
Foreign	(98)			54			16
Total — deferred	(109)			371			621
Total income tax (benefit)/expense	$	(11)		$	442		$	672
Effective income tax rate	5.2		%	26.6		%	23.5		%

The IRA enacted on August 16, 2022, introduced new provisions including a 15% corporate alternative minimum tax and a 1% excise tax on net share repurchases with both taxes effective beginning in fiscal year 2023 for NRG. There is no impact on the Company's provision for income taxes from the CAMT for the year ended December 31, 2023. The Company will reevaluate the impact of the corporate alternative minimum tax upon the potential release of guidance by the U.S. Treasury and the IRS regarding the treatment of unrealized gains and losses on derivative instruments.

The following represented the domestic and foreign components of income before income taxes:

	Year Ended December 31,
(In millions)	2023		2022		2021
U.S.	$	261	$	1,436	$	2,759
Foreign	(474)		227		100
Total	$	(213)	$	1,663	$	2,859

Reconciliations of the U.S. federal statutory tax rate to NRG's effective tax rate were as follows:

	Year Ended December 31,
(In millions, except effective income tax rate)	2023			2022			2021
(Loss)/Income before income taxes	$	(213)		$	1,663		$	2,859
Tax at federal statutory tax rate	(45)			349			600
State taxes	(22)			69			111
Foreign rate differential	(10)			7			(3)
Changes in state valuation allowances	42			(3)			(29)
Permanent differences	31			17			8
Recognition of uncertain tax benefits	12			8			(10)
Deferred impact of state tax rate changes	3			14			(10)
Foreign tax refunds	(17)			—			—
Return to provision adjustments	(5)			—			5
Carbon capture tax credits	—			(19)			—
Income tax (benefit)/expense	$	(11)		$	442		$	672
Effective income tax rate	5.2		%	26.6		%	23.5		%

For the year ended December 31, 2023, NRG's effective income tax rate was lower than the federal statutory tax rate of 21%, primarily due to permanent differences and changes in state valuation allowances.

For the year ended December 31, 2022, NRG's effective income tax rate was higher than the federal statutory tax rate of 21% primarily due to state tax expense partially offset by the recognition of carbon capture tax credits.

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For the year ended December 31, 2021, NRG's effective income tax rate was higher than the federal statutory tax rate of 21% primarily due to state tax expense partially offset by tax benefits from the revaluation of state deferred tax assets, valuation allowance, and settlements of uncertain tax positions.

The temporary differences, which gave rise to the Company's deferred tax assets and liabilities consisted of the following:

	As of December 31,
(In millions)	2023		2022
Deferred tax assets:
U.S. Federal net operating loss carryforwards	$	1,762	$	1,717
State net operating loss carryforwards	367		315
Foreign net operating loss carryforwards	110		104
Deferred revenues	347		—
Difference between book and tax basis of property	353		399
Federal and state tax credit carryforwards	317		393
Deferred compensation, accrued vacation and other reserves	141		93
Interest disallowance carryforward per §163(j) of the Tax Act	132		65
Pension and other postretirement benefits	48		62
Allowance for credit losses	35		33
Equity compensation	24		8
Federal benefit on state uncertain tax positions	13		5
Inventory obsolescence	11		10
U.S. capital loss	1		15
Other	33		22
Total deferred tax assets	3,694		3,241
Deferred tax liabilities:
Intangibles amortization (excluding goodwill)	726		269
Derivatives	156		874
Capitalized contract costs	131		—
Equity method investments	93		82
Goodwill	40		26
Debt discount amortization	26		—
Emissions allowances	18		19
Total deferred tax liabilities	1,190		1,270
Total deferred tax assets less deferred tax liabilities	2,504		1,971
Valuation allowance	(275)		(224)
Total net deferred tax assets, net of valuation allowance	$	2,229	$	1,747

The following table summarizes NRG's net deferred tax position as presented in the consolidated balance sheets:

	As of December 31,
(In millions)	2023		2022
Deferred tax asset	$	2,251	$	1,881
Deferred tax liability	(22)		(134)
Net deferred tax asset	$	2,229	$	1,747

The primary drivers for the increase in the net deferred tax asset from $1.7 billion as of December 31, 2022 to $2.2 billion as of December 31, 2023 is due to unrealized mark-to-market book losses and deferred revenues, partially offset by capitalized contract costs and a step-up in basis of book intangibles associated with the acquisition of Vivint Smart Home.

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Deferred tax assets and valuation allowance

Net deferred tax balance — As of December 31, 2023 and 2022, NRG recorded a net deferred tax asset, excluding valuation allowance, of $2.5 billion and $2.0 billion, respectively. The Company believes certain state net operating losses may not be realizable under the more-likely-than-not measurement and as such, a valuation allowance was recorded as of December 31, 2023 as discussed below.

NOL carryforwards — As of December 31, 2023, the Company had tax-effected cumulative U.S. NOLs consisting of carryforwards for federal and state income tax purposes of $1.8 billion and $367 million, respectively. In addition, NRG has tax-effected cumulative foreign NOL carryforwards of $110 million. The majority of NRG's NOL carryforwards have no expiration date.

 Valuation allowance — As of December 31, 2023, the Company's tax-effected valuation allowance was $275 million, consisting of state NOL carryforwards and foreign NOL carryforwards. The valuation allowance was recorded based on the assessment of cumulative and forecasted pre-tax book earnings and the future reversal of existing taxable temporary differences.

Taxes Receivable and Payable

As of December 31, 2023, NRG recorded a current federal payable of $20 million, a current net state payable of $3 million and a current net foreign receivable of $7 million.

Uncertain tax benefits

NRG has identified uncertain tax benefits with after-tax value of $73 million and $22 million as of December 31, 2023 and 2022, for which NRG has recorded a non-current tax liability of $76 million and $24 million, respectively. The Company recognizes interest and penalties related to uncertain tax benefits in income tax expense. The Company recognized $1 million of interest expense for the year ended December 31, 2023, $1 million for the year ended 2022 and an immaterial amount for the year ended 2021. As of December 31, 2023 and 2022, NRG had cumulative interest and penalties related to these uncertain tax benefits of $3 million and $2 million, respectively.

Tax jurisdictions — NRG is subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state and foreign jurisdictions including operations located in Australia and Canada.

The Company is no longer subject to U.S. federal income tax examinations for years prior to 2020. With few exceptions, state and Canadian income tax examinations are no longer open for years before 2015.

The following table summarizes uncertain tax benefits activity:

	As of December 31,
(In millions)	2023		2022
Balance as of January 1	$	22	$	13
Increase due to current year positions	28		9
Increase due to acquired balance from Vivint Smart Home	23		—
Uncertain tax benefits as of December 31	$	73	$	22

Note 21 — Stock-Based Compensation

The Company's stock-based compensation consists of awards granted under the NRG LTIP and following the Acquisition in March 2023, the Vivint LTIP.

NRG Energy, Inc. Long-Term Incentive Plan

As of December 31, 2023 and 2022, a total of 25,000,000 shares of NRG common stock were authorized for issuance under the NRG LTIP. There were 7,717,139 and 8,179,771 shares of common stock remaining available for grants under the NRG LTIP as of December 31, 2023 and 2022, respectively. The NRG LTIP is subject to adjustments in the event of reorganization, recapitalization, stock split, reverse stock split, stock dividend, and a combination of shares, merger or similar change in NRG's structure or outstanding shares of common stock. As of December 31, 2023, the outstanding awards under the NRG LTIP include restricted stock units, deferred stock units and relative performance stock units.

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Restricted Stock Units

As of December 31, 2023, RSUs granted under the NRG LTIP typically have three-year graded vesting schedules beginning on the grant date. Fair value of the RSUs granted during 2023 and 2022 is derived from the closing price of NRG common stock on the grant date. The following table summarizes the Company's non-vested RSU awards and changes during the year:

	Units	Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2022	856,917	$	40.25
Granted	1,031,469	35.71
Forfeited	(284,076)	34.70
Vested	(393,470)	39.67
Non-vested at December 31, 2023	1,210,840	37.88

The total fair value of RSUs vested during the years ended December 31, 2023, 2022 and 2021 was $20 million, $10 million and $12 million, respectively. The weighted average grant date fair value of RSUs granted during the years ended December 31, 2023, 2022 and 2021 was $35.71, $41.26 and $39.00, respectively.

Deferred Stock Units

DSUs represent the right of a participant to be paid one share of NRG common stock at the end of a deferral period established under the terms of the award. DSUs granted under the NRG LTIP are fully vested at the date of issuance. Fair value of the DSUs, which is based on the closing price of NRG common stock on the date of grant, is recorded as compensation expense in the period of grant.

The following table summarizes the Company's outstanding DSU awards and changes during the year:

	Units	Weighted Average Grant Date Fair Value per Unit
Outstanding at December 31, 2022	418,014	$	27.63
Granted	79,072	34.40
Converted to Common Stock	(53,799)	25.11
Outstanding at December 31, 2023	443,287	29.07

The aggregate intrinsic values for DSUs outstanding as of December 31, 2023, 2022 and 2021 were approximately $23 million, $13 million and $17 million, respectively. The aggregate intrinsic values for DSUs converted to common stock for the years ended December 31, 2023, 2022 and 2021 were $3 million, $1 million and $1 million, respectively. The weighted average grant date fair value of DSUs granted during the years ended December 31, 2023, 2022 and 2021 was $34.40, $45.49 and $32.27, respectively.

Relative Performance Stock Units

RPSUs entitle the recipient to stock upon vesting. The amount of the award is subject to the Company's achievement of certain performance measures over the vesting period. RPSUs are restricted grants where the quantity of shares increases and decreases alongside the Company's Total Shareholder Return ("TSR"), relative to the TSR of the Company's current proxy peer group and the total returns of select indexes, or Peer Group. For RPSU's granted in 2022 and forward, the peer group consists of the companies that comprise the Standard & Poor’s 500 Index on the first day of the performance period. Each RPSU represents the potential to receive NRG common stock after the completion of the performance period, typically three years of service from the date of grant. The number of shares of NRG common stock to be paid (if any) as of the vesting date for each RPSU will depend on the Company’s percentile rank within the Peer Group. The number of shares of common stock to be paid as of the vesting date for each RPSU is linearly interpolated for TSR performance between the following points: (i) 0% if ranked below the 25th percentile; (ii) 25% if ranked at the 25th percentile; (iii) 100% if ranked at the 55th percentile (or the 65th percentile if the Company's absolute TSR is less than negative 15%); and (iv) 200% if ranked at the 75th percentile or above.

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The following table summarizes the Company's non-vested RPSU awards and changes during the year:

	Units	Weighted Average Grant-Date Fair Value per Unit
Non-vested at December 31, 2022	795,335	$	50.23
Granted	617,510	39.46
Forfeited(a)	(737,227)	45.61
Vested	(3,729)	50.28
Non-vested at December 31, 2023	671,889	46.27

(a)Includes January 2023 vestings that occurred at a 0% payout as well as forfeitures due to the departure of certain officers

The weighted average grant date fair value of RPSUs granted during the years ended December 31, 2023, 2022 and 2021, was $39.46, $57.41 and $46.78, respectively.

The fair value of RPSUs is estimated on the date of grant using a Monte Carlo simulation model and expensed over the service period, which equals the vesting period. Significant assumptions used in the fair value model with respect to the Company's RPSUs are summarized below:

	2023		2022		2021(a)
Expected volatility	41.35	%	37.54	%	34.05	%
Expected term (in years)	3		3		3
Risk free rate	4.18	%	0.97	%	0.17	%

(a)Assumptions pertain to the main award granted in January 2021. Additional 60,815 RPSUs were granted in September 2021 with a risk free rate of 0.42% and expected volatility of 37.38%

The expected volatility is calculated based on NRG's historical stock price volatility data over the period commensurate with the expected term of the RPSU, which equals the vesting period.

Vivint Smart Home Long-Term Incentive Plan

Effective March 10, 2023, in connection with the Vivint Smart Home Acquisition, as discussed in Note 4, Acquisitions and Dispositions, NRG assumed the Vivint Smart Home, Inc. Long-Term Incentive Plan, or Vivint LTIP. In addition to the rollover awards converted as part of the Acquisition, the Vivint LTIP provides for issuances of time-based restricted stock units and performance-based restricted stock units. As of December 31, 2023, 17,500,000 shares of NRG common stock were authorized for issuance under the Vivint LTIP, and there were 12,749,736 shares of common stock remaining available for grants.

Restricted Stock Units

As of December 31, 2023, RSUs under the Vivint LTIP include RSUs which were granted prior to the Acquisition and were converted into awards that will vest as NRG common stock ("Rollover RSUs"). These awards typically had four-year graded vesting schedules beginning on the grant date. The fair value of the Rollover RSUs is based on the fair value of NRG common stock on the Acquisition date after applying the conversion ratio as per the Merger Agreement. The RSUs that were granted following the Acquisition date are typically subject to the same terms as the RSUs under the NRG LTIP.

The following table summarizes the non-vested RSUs under the Vivint LTIP and changes during the year:

	Rollover RSUs			RSUs granted following the Acquisition
	Units	Weighted Average Grant Date Fair Value per Unit		Units	Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2022	—	$	—	—	$	—
Rollover RSUs at the Acquisition date	4,553,998	31.63		—	—
Granted following the Acquisition date	—	—		895,827	35.24
Forfeited	(288,776)	31.63		(110,531)	35.21
Vested	(1,280,321)	31.63		(4,998)	35.21
Non-vested at December 31, 2023	2,984,901	31.63		780,298	35.24

The total fair value of RSUs vested during the year ended December 31, 2023 was $66 million.

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Performance Stock Units

As of December 31, 2023, PSUs granted under the Vivint LTIP are generally granted under the same terms as the PSUs granted under the NRG LTIP, and are valued using the same methods and assumptions. During the year ended December 31, 2023, 102,837 PSUs were granted at a weighted average grant date fair value per unit of $44.96 and remain outstanding as of year end.

Supplemental Information

The following table summarizes NRG's total compensation expense recognized for the years presented, as well as total non-vested compensation costs not yet recognized and the period over which this expense is expected to be recognized as of December 31, 2023, for each of the types of awards issued under the LTIPs. Minimum tax withholdings of $22 million, $6 million, and $9 million for the years ended December 31, 2023, 2022, and 2021, respectively, are reflected as a reduction to additional paid-in capital on the Company's consolidated balance sheets.

							Non-vested Compensation Cost
(In millions, except weighted average data)	Compensation Expense						Unrecognized Total Cost		Weighted Average Recognition Period Remaining (In years)
	Year Ended December 31,						As of December 31,
Award	2023		2022		2021		2023		2023
RSUs under NRG LTIP	$	20	$	15	$	9	$	29	1.61
RSUs under Vivint LTIP	76		—		—		69		1.82
PSUs under Vivint LTIP	2		—		—		3		2.25
DSUs	2		2		2		—		0.00
RPSUs	3		11		9		17		1.69
PRSUs under NRG LTIP(a)	12		6		7		15		1.74
PRSUs under Vivint LTIP(a)	8		—		—		14		2.29
Total	$	123	$	34	$	27	$	147
Tax detriment recognized	$	2	$	3	$	2

(a)Phantom Restricted Stock Units, PRSUs, are liability-classified time-based awards that typically vest ratably over a three-year period. The amount to be paid upon vesting is based on NRG's closing stock price for the period

Note 22 — Related Party Transactions

NRG provides services to some of its related parties, who are accounted for as equity method investments, under operations and maintenance agreements. Fees for the services under these agreements include recovery of NRG's costs of operating the plants. Certain agreements also include fees for administrative service, a base monthly fee, profit margin and/or annual incentive bonus.

The following table summarizes NRG's material related party transactions with third-party affiliates:

	Year Ended December 31,
(In millions)	2023		2022		2021
Revenues from Related Parties Included in Revenues
Gladstone	$	4	$	4	$	4
Ivanpah(a)	78		42		39
Midway-Sunset	2		6		6
Total	$	84	$	52	$	49

(a)Includes fees under project management agreements with each project company

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Note 23 — Commitments and Contingencies

Commitments

NRG has entered into long-term contractual arrangements related to energy products, including power purchases, gas transportation and storage, and fuel and transportation services. These contracts are not included in the consolidated balance sheet as of December 31, 2023.

As of December 31, 2023, the Company's minimum commitments under such outstanding agreements are estimated as follows:

Period	(In millions)
2024	$	573
2025	836
2026	540
2027	364
2028	292
Thereafter	823
Total(a)	$	3,428

(a)The year 2024 does not include an additional $978 million of short-term commitments

The Company's actual costs may be significantly higher than these estimated minimum unconditional long-term firm commitments with remaining term in excess of one year. For the years ended December 31, 2023, 2022 and 2021, the costs of fuel and purchased energy were $13.4 billion, $19.6 billion and $13.4 billion, respectively.

First Lien Structure

NRG has granted first liens to certain counterparties on a substantial portion of property and assets owned by NRG and the guarantors of its senior debt. NRG uses the first lien structure to reduce the amount of cash collateral and letters of credit that it would otherwise be required to post from time to time to support its obligations under out-of-the-money hedges. To the extent that the underlying hedge positions for a counterparty are out-of-the-money to NRG, the counterparty would have a claim under the first lien program. As of December 31, 2023, all hedges under the first liens were in-the-money on a counterparty aggregate basis.

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. NRG records accruals 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 accrual for the applicable legal matters, including regulatory and environmental matters as further discussed in Note 24, Regulatory Matters, and Note 25, Environmental Matters. In addition, legal costs are expensed as incurred. Management has assessed each of the following matters based on current information and made a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought, and the probability of success. Unless specified below, the Company is unable to predict the outcome of these legal proceedings 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 accruals and that such difference could be material.

In addition to the legal proceedings noted below, NRG 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 NRG's consolidated financial position, results of operations, or cash flows.

Environmental Lawsuits

Sierra club et al. v. Midwest Generation LLC — In 2012, several environmental groups filed a complaint against Midwest Generation with the Illinois Pollution Control Board ("IPCB") alleging violations of environmental law resulting in groundwater contamination. In June 2019, the IPCB found in an interim order that Midwest Generation violated the law because it had improperly handled coal ash at four facilities in Illinois and caused or allowed coal ash constituents to impact groundwater. On September 9, 2019, Midwest Generation filed a Motion to Reconsider numerous issues, which the court granted in part and denied in part on February 6, 2020. In 2023, the IPCB held hearings to determine the appropriate relief. Midwest Generation has been working with the Illinois EPA to address the groundwater issues since 2010.

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Consumer Lawsuits

Similar to other energy service companies operating in the industry, from time-to-time, the Company and/or its subsidiaries may be subject to consumer lawsuits in various jurisdictions where they sell natural gas and electricity.

Variable Price Cases — In the cases set forth below, referred to as the Variable Price Cases, such actions involve consumers alleging that one of the Company’s ESCOs promised that consumers would pay the same or less than they would have paid if they stayed with their default utility or previous energy supplier. The underlying claims of each case are similar and the Company continues to deny the allegations and is vigorously defending these matters. These matters were known and accrued for at the time of each acquisition.

XOOM Energy

Mirkin v. XOOM Energy (E.D.N.Y. Aug. 2019) is a defendant in a putative class action lawsuit pending in New York. The Court denied XOOM's motion for summary judgment and granted class certification. The Second Circuit denied XOOM's request to appeal the class certification grants. XOOM plans to challenge Mirkin's expert testimony to further hamper Mirkin's ability to support its case.

Direct Energy

There was one putative class action pending against Direct Energy: Richard Schafer v. Direct Energy (W.D.N.Y. Dec. 2019; on appeal 2nd Cir. N.Y.) - The Second Circuit sent the matter back to the trial court in December 2021. After discovery, Direct Energy filed summary judgment. Direct Energy won summary judgment and Schafer appealed. The appeal is fully briefed. Oral argument occurred on October 25, 2023. The Second Circuit upheld the trial court's grant of summary judgment in favor of Direct Energy.

Telephone Consumer Protection Act ("TCPA") Cases — In the cases set forth below, referred to as the TCPA Cases, such actions involve consumers alleging violations of the Telephone Consumer Protection Act of 1991, as amended, by receiving calls, texts or voicemails without consent in violation of the federal Telemarketing Sales Rule, and/or state counterpart legislation. The underlying claims of each case are similar. The Company denies the allegations asserted by plaintiffs and intends to vigorously defend these matters. These matters were known and accrued for at the time of the acquisition.

There are two putative class actions pending against Direct Energy: (1) Holly Newman v. Direct Energy, LP (D. Md Sept 2021) - Direct Energy filed its Motion to Dismiss asserting the ruling in the Brittany Burk v. Direct Energy (S.D. Tex. Feb 2019) preempts the Plaintiff's ability to file suit based on the same facts. The Court denied Direct Energy's motion stating the Court does not have the benefit of all of the facts that were in front of the Burk court to issue a similar ruling. On October 19, 2022, Direct Energy filed a Motion to Transfer Venue asking the Court to transfer the case to the Southern District where the Burk case was filed. On April 12, 2023, the Court granted Direct Energy’s Motion to Transfer Venue, moving to the case to the Southern District of Texas; and (2) Matthew Dickson v. Direct Energy (N.D. Ohio Jan. 2018) - The case was stayed pending the outcome of an appeal to the Sixth Circuit based on the unconstitutionality of the TCPA during the period from 2015-2020. The Sixth Circuit found the TCPA was in effect during that period and remanded the case back to the trial court. Direct Energy refiled its motions along with supplements. On March 25, 2022, the Court granted summary judgment in favor of Direct Energy and dismissed the case. Dickson appealed. The Sixth Circuit found that Dickson has standing and reversed the trial court's dismissal of the case. The matter is back at the trial court. The parties will conduct further fact discovery and expert discovery and are likely to resubmit motions for further review by the Court.

Sales Practice Lawsuits

There are three litigation matters relating to claims made by Vivint Smart Home competitors against Vivint Smart Home alleging, among other things, that Vivint Smart Home's sales representatives used deceptive sales practices. These matters were known and accrued for at the time of the acquisition. The three matters are: (1) CPI Security Systems, Inc. ("CPI") v. Vivint Smart Home, Inc. (W.D.N.C. Sept. 2020). The CPI matter that was filed in 2020 went to trial, and in February 2023, the jury issued a verdict against Vivint Smart Home, in favor of CPI for $50 million of compensatory damages and an additional $140 million of punitive damages. Vivint Smart Home has filed its notice of appeal and is awaiting a briefing schedule. While Vivint Smart Home believes the CPI jury verdict is not legally or factually supported and intends to pursue post judgment remedies and file an appeal, there can be no assurance that such defense efforts will be successful; (2) ADT LLC, et al. ("ADT") v. Vivint Smart Home, Inc. f/k/a Mosaic Acquisition Corporation, et al.(S.D.Fl. Aug. 2020). The parties mediated in May 2023 and agreed on a settlement. In June 2023, the Court granted final approval of the settlement, which was paid in June 2023; and (3) Alert 360 Opco, Inc, et al. ("Alert 360") v. Vivint Smart Home, Inc., et al (N.D.Ok. March 2023). On March 1, 2023, Alert 360 filed a complaint against Vivint Smart Home alleging, among other things, deceptive sales practices. The parties settled the dispute in October 2023 and the case was dismissed.

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Patent Infringement Lawsuits

SB IP Holdings LLC (“Skybell”) v. Vivint Smart Home, Inc. — On October 23, 2023, a jury in the U.S. District Court, Eastern District of Texas, Sherman Division, issued a verdict against the Company in favor of Skybell for $45 million in damages for patent infringement. The patents that were the basis for the claims made by Skybell were ruled invalid by the U.S. International Trade Commission in November 2021. In accordance with advice by legal counsel, the Company does not believe the verdict is legally supported and will pursue post-judgment and appellate remedies along with any other legal options available.

Contract Disputes

Alarm.com — In September 2022, Vivint Smart Home sent Alarm.com a notice asserting that it was no longer obligated to pay certain license fees under the Patent Cross License Agreement between the parties on the basis that Vivint Smart Home no longer practices any claim under any valid Alarm.com patent and, therefore, no license fees are due. Alarm.com filed an arbitration demand against Vivint Smart Home alleging, among other things, breach of the agreement due to continued use of the patents in question. The parties have resolved all outstanding litigation and entered into a long-term intellectual property licensing agreement.

STP — In July 2023, the partners in STP, CPS and Austin Energy, initiated a lawsuit and filed to intervene in the license transfer application with the NRC, claiming a right of first refusal exists in relation to the proposed sale of NRG South Texas' 44% interest in STP to Constellation. NRG believes the claims set forth by CPS and Austin Energy in the lawsuit and the NRC proceedings are without merit and intends to vigorously defend against them. For further discussion of the transaction, see Note 4, Acquisitions and Dispositions.

Winter Storm Uri Lawsuits

The Company has been named in certain property damage and wrongful death claims that have been filed in connection with Winter Storm Uri in its capacity as a generator and a REP. Most of the lawsuits related to Winter Storm Uri are consolidated into a single multi-district litigation matter in Harris County District Court. NRG's REPs have since been severed from the multi-district litigation and will be seeking dismissal in any remaining cases. As a power generator, the Company is named in various cases with claims ranging from: wrongful death; personal injury only; property damage and personal injury; property damage only; and subrogation. The First Court of Appeals conditionally granted the generators' mundamus relief, ordering the trial court to grant the generator defendents' Motions to Dismiss. The Company expected the Plaintiffs to challenge this ruling. The Company intends to vigorously defend these matters.

Indemnifications and Other Contractual Arrangements

Washington-St. Tammany and Claiborne Electric Cooperative v. LaGen — On June 28, 2017, plaintiffs Washington-St. Tammany Electric Cooperative, Inc. and Claiborne Electric Cooperative, Inc. filed a lawsuit against LaGen in the United States District Court for the Middle District of Louisiana. The plaintiffs claimed breach of contract against LaGen for allegedly improperly charging the plaintiffs for costs related to the installation and maintenance of certain pollution control technology. Plaintiffs sought damages for the alleged improper charges and a declaration as to which charges were proper under the contract. On February 4, 2019, NRG sold the South Central Portfolio, including the entities subject to this litigation. However, NRG has agreed to indemnify the purchaser for certain losses suffered in connection with this litigation. In February 2020, the federal court dismissed this lawsuit without prejudice for lack of subject matter jurisdiction. On March 17, 2020, plaintiffs filed a lawsuit in the Nineteenth Judicial District Court for the Parish of East Baton Rouge in Louisiana alleging substantially the same matters, which was dismissed on October 2, 2023 pursuant to a settlement agreement.

Note 24 — Regulatory Matters

NRG operates in a highly regulated industry and is subject to regulation by various federal, state and provincial agencies. As such, NRG is affected by regulatory developments at the federal, state and provincial levels and in the regions in which NRG operates.

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

California Station Power — As the result of unfavorable final and non-appealable litigation, the Company accrued a liability associated with consumption of station power at the Company's Encina power plant facility in California after August 30, 2010. The Company has established an appropriate accrual pending potential regulatory action by San Diego Gas & Electric regarding the Company's Encina facility.

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Federal Trade Commission Investigation — In 2019, Vivint Smart Home received a civil investigative demand from the staff of the Federal Trade Commission (“FTC”) concerning potential violations of the Fair Credit Reporting Act and the “Red Flags Rule” thereunder, and the FTC Act. In April 2021, Vivint Smart Home entered into a settlement with the FTC that resolved this investigation. As part of this settlement, which was approved by a federal court on May 3, 2021, Vivint Smart Home paid $20 million and agreed to implement various additional compliance related measures ("Stipulated Order"). The Company is currently in the process of administering the terms of the Stipulated Order, which includes multiple undertakings by the Company. The Company is engaged in ongoing discussions with the staff of the FTC regarding the Company’s compliance with the terms of the Stipulated Order. Under the terms of the Stipulated Order, Vivint Smart Home is required to undertake biennial assessments by an independent third-party assessor (the "Assessor"), which reviews Vivint Smart Home’s compliance program and provides a report on Vivint Smart Home’s ongoing compliance with the Stipulated Order. Since its inception until December 31, 2023, Vivint Smart Home has completed its initial assessment and its first biennial assessment as required by the Stipulated Order. In addition, Vivint Smart Home has voluntarily undertaken six quarterly audits by the appointed Assessor. In all the assessments, Vivint Smart Home received a report from the Assessor with no findings of non-compliance of any kind.

New York State Public Service Commission ("NYSPSC") - Notice of Apparent Violation — The NYSPSC issued an order referred to as the Retail Reset Order in December 2019 that limited ESCO's offers for electric and natural gas to three compliant products: guaranteed savings from the utility default rate, a fixed term capped at 5% of the rolling 12-month average utility default rate, or NY-sourced renewable energy that is at least 50% greater than the prevailing NY Renewable Energy Standard for load serving entities. The order effectively limited ESCO offers to natural gas customers to only the guaranteed savings and capped fixed term compliant products because no equivalent renewable energy product exists for natural gas. NRG took action to comply with the order when it became effective April 16, 2021. On January 8, 2024, the NYSPSC notified eight of NRG's retail energy suppliers (serving both electricity and natural gas) of alleged non-compliance with New York regulatory requirements. Among other items, the notices allege that the NRG suppliers did not transition existing residential customers to one of the three compliant products authorized by the NYSPSC following the effective date of the order. NRG responded to the notices in February 2024. The outcome of this process has the potential to negatively impact the retail business in New York.

Note 25 — Environmental Matters

NRG is subject to a wide range of environmental laws in the development, construction, ownership and operation of power plants. These laws generally require that governmental permits and approvals be obtained before construction and maintained during operation of power plants. The electric generation industry has been facing increasingly stringent requirements regarding air quality, GHG emissions, combustion byproducts, water discharge and use, and threatened and endangered species. In general, future laws are expected to require the addition of emissions controls or other environmental controls or to impose additional restrictions on the operations of the Company's facilities, which could have a material effect on the Company's consolidated financial position, results of operations, or cash flows. The Company has elected to use a $1 million disclosure threshold, as permitted, for environmental proceedings to which the government is a party.

Air

CPP/ACE Rules — In 2019, the EPA promulgated the ACE rule, which rescinded the CPP, which had sought to broadly regulate CO2 emissions from the power sector. The ACE rule required states that have coal-fired EGUs to develop plans to seek heat rate improvements from coal-fired EGUs. On January 19, 2021, the D.C. Circuit vacated the ACE rule (but on February 22, 2021, at the EPA's request, stayed the issuance of the portion of the mandate that would vacate the repeal of the CPP). On June 30, 2022, the U.S. Supreme Court held that the "generation shifting" approach in the CPP exceeded the powers granted to the EPA by Congress. The Court did not address the related issues of whether the EPA may adopt only measures applied at each source. On May 23, 2023, the EPA proposed significantly revising the manner in which new and existing EGU's GHG emissions should be regulated including using hydrogen as a fuel, capturing and storing/sequestering CO2 and requiring new units to be more efficient. The EPA has stated that it intends to finalize these revisions in 2024. The Company expects that the final rule will be challenged in the courts and accordingly uncertain over the next several years.

Cross-State Air Pollution Rule ("CSAPR") — On March 15, 2023, the EPA signed and released a prepublication of a final rule that sought to significantly revise the CSAPR to address the good-neighbor obligations of the 2015 ozone NAAQS for 23 states after earlier having disapproved numerous state plans to address the issue. Several states, including Texas, challenged the EPA's disapproval of their state plans. On May 1, 2023, the United States Court of Appeals for the Fifth Circuit stayed the EPA's disapproval of Texas' and Louisiana's state plans, which disapprovals are a condition precedent to the EPA imposing its plan on Texas and Louisiana. Several other states are also similarly situated because of similar stays. Nonetheless, on June 5, 2023, the EPA published this rule in the Federal Register. On July 31, 2023, the EPA promulgated an interim final rule that addresses the various judicial orders that have stayed several State-Implementation-Plan disapprovals by limiting the effectiveness of certain requirements of the final rule promulgated on June 5, 2023 in Texas and five other states. The final rule decreases, over time, the ozone-season NOx allowances allocated to generators in the states not affected by the judicial stays

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beginning in 2023 by assuming that participants in this cap-and-trade program had or would optimize existing NOx controls and later install additional NOx controls. The Company cannot predict the outcome of the legal challenges to the: (i) various state disapprovals; (ii) the final rule promulgated on June 5, 2023; and (iii) the interim final rule promulgated on July 31, 2023 that seeks to address the judicial orders.

Regional Haze Proposal — On May 2023, the EPA proposed to withdraw the existing Texas Sulfur Dioxide Trading Program and replace it with unit-specific SO2 limits for 12 units in Texas to address requirements to improve visibility at National Parks and Wilderness areas. If finalized as proposed, the rule would result in more stringent SO2 limits for two of the Company's coal-fired units in Texas. The Company cannot predict the outcome of this proposal.

Water

Effluent Limitations Guidelines — In 2015, the EPA revised the ELG for Steam Electric Generating Facilities, which imposed more stringent requirements (as individual permits were renewed) for wastewater streams from FGD, fly ash, bottom ash, and flue gas mercury control. On September 18, 2017, the EPA promulgated a final rule that, among other things, postponed the compliance dates to preserve the status quo for FGD wastewater and bottom ash transport water by two years to November 2020 until the EPA amended the rule. On October 13, 2020, the EPA amended the 2015 ELG rule by: (i) altering the stringency of certain limits for FGD wastewater; (ii) relaxing the zero-discharge requirement for bottom ash transport water; and (iii) changing several deadlines. In October 2021, NRG informed its regulators that the Company intends to comply with the ELG by ceasing combustion of coal by the end of 2028 at its domestic coal units outside of Texas, and installing appropriate controls by the end of 2025 at its two plants that have coal-fired units in Texas. On March 29, 2023, the EPA proposed revisions to the ELG and sought comments, which the EPA is analyzing.

Byproducts

In 2015, the EPA finalized a rule regulating byproducts of coal combustion (e.g., ash and gypsum) as solid wastes under the RCRA. On August 21, 2018, the D.C. Circuit found, among other things, that the EPA had not adequately regulated unlined ponds and legacy surface impoundments. On August 28, 2020, the EPA finalized "A Holistic Approach to Close Part A: Deadline to Initiate Closure," which amended the April 2015 Rule to address the August 2018 D.C. Circuit decision and extend some of the deadlines. On November 12, 2020, the EPA finalized "A Holistic Approach to Closure Part B: Alternative Demonstration for Unlined Surface Impoundments," which further amended the April 2015 Rule to, among other things, provide procedures for requesting approval to operate existing ash impoundments with an alternative liner. On May 23, 2023, the EPA proposed establishing requirements for: (i) inactive (or legacy) surface impoundments at inactive facilities and (ii) all CCR management units (regardless of how or when the CCR was placed) at regulated facilities. NRG anticipates further rulemaking related to legacy surface impoundments and the Federal Permit Program.

Note 26 — Cash Flow Information

Detail of supplemental disclosures of cash flow and non-cash investing and financing information was:

	Year Ended December 31,
(In millions)	2023		2022		2021
Interest paid, net of amount capitalized	$	548	$	383	$	433
Income taxes paid, net of refunds	48		66		32
Non-cash investing activities:
Decreases to fixed assets for accrued capital expenditures	—		(68)		(16)

Note 27 — Guarantees

NRG and its subsidiaries enter into various contracts that include indemnification and guarantee provisions as a routine part of the Company's business activities. Examples of these contracts include asset purchases and sale agreements, commodity sale and purchase agreements, retail contracts, joint venture agreements, EPC agreements, operation and maintenance agreements, service agreements, settlement agreements, and other types of contractual agreements with vendors and other third parties, as well as affiliates. These contracts generally indemnify the counterparty for tax, environmental liability, litigation and other matters, as well as breaches of representations, warranties and covenants set forth in these agreements. The Company is obligated with respect to customer deposits associated with the Company's retail operations. In some cases, NRG's maximum potential liability cannot be estimated, since the underlying agreements contain no limits on potential liability.

160

The following table summarizes the maximum potential exposures that can be estimated for NRG's guarantees, indemnities, and other contingent liabilities by maturity:

	By Remaining Maturity at December 31,
(In millions)	2023
Guarantees	Under 1 Year		1-3 Years		3-5 Years		Over 5 Years		Total		2022 Total
Letters of credit and surety bonds	$	4,555	$	37	$	—	$	—	$	4,592	$	5,211
Asset sales guarantee obligations	13		24		22		67		126		409
Other guarantees	—		—		—		27		27		15
Total guarantees	$	4,568	$	61	$	22	$	94	$	4,745	$	5,635

Letters of credit and surety bonds — As of December 31, 2023, NRG and its consolidated subsidiaries were contingently obligated for a total of $4.6 billion under letters of credit and surety bonds. Most of these letters of credit and surety bonds are issued in support of the Company's obligations to perform under commodity agreements and obligations associated with future closure and maintenance of ash sites, as well as for financing or other arrangements. A majority of these letters of credit and surety bonds expire within one year of issuance, and it is typical for the Company to renew them on similar terms.

The material indemnities, within the scope of ASC 460, are as follows:

Asset sales — The purchase and sale agreements which govern NRG's asset or share investments and divestitures customarily contain guarantees and indemnifications of the transaction to third parties. The contracts indemnify the parties for liabilities incurred as a result of a breach of a representation or warranty by the indemnifying party, changes in tax laws or for pre-existing environmental matters. These obligations generally have a discrete term and are intended to protect the parties against risks that are difficult to predict or estimate at the time of the transaction. In several cases, the contract limits the liability of the indemnifier. NRG has no reason to believe that the Company currently has any material liability relating to such routine indemnification obligations included in the table above, except for the California property tax indemnity for estimated increases in California property taxes of certain solar properties that the Company agreed to indemnify, as part of the agreement to sell NRG Yield and the Renewables Platform. The California property tax indemnity is estimated to be $126 million as of December 31, 2023 and is included in the above table under asset sales guarantee obligations.

Other guarantees — NRG has issued other guarantees of obligations including payments under certain agreements with respect to certain of its unconsolidated subsidiaries, payment or performance by fuel providers and payment or reimbursement of credit support and deposits. The Company does not believe that it will be required to perform under these guarantees.

Other indemnities — Other indemnifications NRG has provided cover operational, tax, litigation and breaches of representations, warranties and covenants. NRG has also indemnified, on a routine basis in the ordinary course of business, consultants or other vendors who have provided services to the Company. NRG's maximum potential exposure under these indemnifications can range from a specified dollar amount to an indeterminate amount, depending on the nature of the transaction. Total maximum potential exposure under these indemnifications is not estimable due to uncertainty as to whether claims will be made or how they will be resolved. NRG does not have any reason to believe that the Company will be required to make any material payments under these indemnity provisions.

Because many of the guarantees and indemnities NRG issues to third parties and affiliates do not limit the amount or duration of its obligations to perform under them, there exists a risk that the Company may have obligations in excess of the amounts described above. For those guarantees and indemnities that do not limit the Company's liability exposure, it may not be able to estimate what the Company's liability would be, until a claim is made for payment or performance, due to the contingent nature of these contracts.

Note 28 — Jointly Owned Plant     

NRG owns an undivided interest in Cedar Bayou. Cedar Bayou is maintained and operated pursuant to its joint ownership participation and operating agreement. NRG is responsible for its subsidiaries' share of operating costs and direct expenses and includes its proportionate share of the facility and related revenues and direct expenses in the jointly-owned plant in the corresponding balance sheet and income statement captions of the Company's consolidated financial statements.

The following table summarizes NRG's proportionate ownership interest in the Company's jointly-owned facility:

(In millions unless otherwise stated)
As of December 31, 2023	Ownership Interest		Property, Plant & Equipment		Accumulated Depreciation		Construction in Progress
Cedar Bayou Unit 4, Baytown, TX	50.00	%	$	222	$	(115)	$	2

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SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

For the Years Ended December 31, 2023, 2022 and 2021

(In millions)	Balance at Beginning of Period		Charged to Costs and Expenses		Charged to Other Accounts		Deductions			Balance at End of Period
Allowance for credit losses, deducted from accounts receivable and other non-current assets
Year Ended December 31, 2023	$	133	$	251	$	35	$	(274)	(a)	$	145
Year Ended December 31, 2022	683		11		—		(561)		(a)	133
Year Ended December 31, 2021	67		698		112		(194)		(a)	683
Income tax valuation allowance, deducted from deferred tax assets
Year Ended December 31, 2023	$	224	$	42	$	9	$	—		$	275
Year Ended December 31, 2022	248		(20)		(4)		—			224
Year Ended December 31, 2021	266		(29)		11		—			248

(a) Represents principally net amounts charged as uncollectible

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EXHIBIT INDEX

Number	Description	Method of Filing
2.1	Third Amended Joint Plan of Reorganization of GenOn Energy, Inc. and its Debtor Affiliates.	Incorporated herein by reference to Exhibit 2.1 to the Registrant's current report on Form 8-K filed on December 18, 2017.
2.2†^	Purchase and Sale Agreement, dated as of February 6, 2018, by and among NRG Energy, Inc. and NRG Repowering Holdings LLC, and GIP III Zephyr Acquisition Partners, L.P.	Incorporated herein by reference to Exhibit 2.9 to the Registrant's annual report on Form 10-K filed on March 1, 2018.
2.3^	Purchase and Sale Agreement, dated as of February 6, 2018, by and between NRG Energy, Inc., NRG South Central Generating LLC, and Cleco Energy LLC.	Incorporated herein by reference to Exhibit 2.10 to the Registrant's annual report on Form 10-K filed on March 1, 2018.
2.4‡	Purchase and Sale Agreement dated as of February 28, 2021 by and between NRG Energy, Inc., and Generation Bridge Acquisition, LLC, as a Purchaser	Incorporated herein by reference to Exhibit 2.1 to the Registrant's quarterly report on Form 10-Q filed on May 6, 2021.
2.5^	Agreement and Plan of Merger dated as of December 6, 2022, by and among the Company, Merger Sub and Vivint.	Incorporated herein by reference to Exhibit 2.1 to the Registrant's Current Report on Form 8-K, filed on December 6, 2022.
2.6	Equity Purchase Agreement, dated May 31, 2023 by and among Constellation Energy Generation, LLC, as Buyer and Texas Genco GP, LLC, Texas Genco LP, LLC, together, Seller.	Incorporated herein by reference to Exhibit 2.1 to the Registrant's current report on Form 8-K filed on June 1, 2023.
2.7	Amendment No.1 to Equity Purchase Agreement dated September 29, 2023 by and among Constellation Energy Generation, LLC. as Buyer and Texas Genco GP, LLC, together, Seller	Filed herewith.
2.8	Amendment No. 2 to Equity Purchase Agreement dated November 1, 2023 by and among Constellation Energy Generation, LLC. as Buyer and Texas Genco GP, LLC, together, Seller	Filed herewith.
2.9	Amendment No. 3 to Equity Purchase Agreement dated November 1, 2023 by and among Constellation Energy Generation, LLC. as Buyer and Texas Genco GP, LLC, together, Seller	Filed herewith.
3.1	Amended and Restated Certificate of Incorporation.	Incorporated herein by reference to Exhibit 3.1 to the Registrant's quarterly report on Form 10-Q filed on May 3, 2012.
3.2	Certificate of Amendment to Amended and Restated Certificate of Incorporation.	Incorporated herein by reference to Exhibit 3.1 to the Registrant's current report on Form 8-K filed on December 14, 2012.
3.3	Sixth Amended and Restated By-Laws.	Incorporated herein by reference to Exhibit 3.2 to the Registrant's current report on Form 8-K filed on December 2, 2022.
3.4	Series A Preferred Stock Certificate of Designation filed with the Secretary of the State of Delaware on March 9, 2023.	Incorporated herein by reference to Exhibit 3.1 to the Registrant's current report on Form 8-K filed on March 10, 2023.
4.1	Specimen of Certificate representing common stock of NRG Energy, Inc.	Incorporated herein by reference to Exhibit 4.3 to the Registrant's quarterly report on Form 10-Q filed on August 4, 2006.
4.2	Base Indenture, dated May 28, 2019, between NRG Energy, Inc. and Delaware Trust Company, as trustee	Incorporated herein by reference to Exhibit 4.1 to the Registrant's Current Report on Form 8-K filed on May 30, 2019.
4.3	Supplemental Indenture, dated May 28, 2019, among NRG Energy, Inc., the guarantors named therein and Delaware Trust Company, as trustee, containing Form 3.750% Senior Secured First Lien Notes due 2024 and Form of 4.440% Senior Secured First Lien Notes due 2029	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K filed on May 30, 2019.
4.4	Base Indenture, dated December 2, 2020, between NRG Energy, Inc. and Deutsche Bank Trust Company Americas, as trustee, pertaining to the Secured Notes.	Incorporated herein by reference to Exhibit 4.1 to the Registrant's Current Report on Form 8-K, filed on December 4, 2020.
4.5	Supplemental Indenture, dated December 2, 2020, among NRG Energy, Inc., the guarantors named therein and Deutsche Bank Trust Company Americas, as trustee, containing Form of 2.000% Senior Secured First Lien Notes due 2025 and Form of 2.450% Senior Secured First Lien Notes due 2027	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K, filed on December 4, 2020.

163

4.6	Supplemental Indenture, dated March 9, 2023, among NRG Energy, Inc., the guarantors named therein and Deutsche Bank Trust Company Americas, as trustee, containing Form of 7.000% Senior Secured First Lien Notes Due 2033	Incorporated herein by reference to Exhibit 4.2 to the Registrant's current report on Form 8-K filed on March 10, 2023.
4.7	Base Indenture, dated May 23, 2016, between NRG Energy, Inc. and Delaware Trust Company (as successor in interest to Law Debenture Trust Company of New York), as trustee.	Incorporated herein by reference to Exhibit 4.1 to the Registrant's Current Report on Form 8-K filed on May 23, 2016.
4.8	Third Supplemental Indenture, dated August 2, 2016, among NRG Energy, Inc., the guarantors named therein and Law Debenture Trust Company of New York containing Form of 6.625% Senior Notes due 2027.	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K, filed on August 3, 2016.
4.9	Fourth Supplemental Indenture, dated December 7, 2017, among NRG Energy, Inc., the guarantors named therein and Delaware Trust Company, as trustee, containing Form of 5.750% Senior Notes due 2028.	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K, filed on December 8, 2017.
4.10	Fifth Supplemental Indenture, dated May 14, 2019, among NRG Energy, Inc., the guarantors named therein and Delaware Trust Company, as trustee, containing Form of 5.250% Senior Notes due 2029.	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K filed on May 16, 2019.
4.11	Base Indenture, dated December 2, 2020, between NRG Energy, Inc. and Deutsche Bank Trust Company Americas, as trustee, pertaining to the Unsecured notes.	Incorporated herein by reference to Exhibit 4.5 to the Registrant's Current Report on Form 8-K, filed on December 4, 2020.
4.12	Supplemental Indenture, dated December 2, 2020, among NRG Energy, Inc., the guarantors named therein and Deutsche Bank Trust Company Americas, as trustee, containing Form of 3.375% Senior Notes due 2029 and Form of 3.625% Senior Notes due 2031.	Incorporated herein by reference to Exhibit 4.6 to the Registrant's Current Report on Form 8-K, filed on December 4, 2020.
4.13	Second Supplemental Indenture, dated August 23, 2021, among NRG Energy, Inc., the guarantors named therein and Deutsche Bank Trust Company Americas, as trustee, containing Form of 3.875% Senior Notes due 2032.	Incorporated herein by reference to Exhibit 4.2 to the Registrant's Current Report on Form 8-K, filed on August 23, 2021.
4.14	Indenture, dated May 24, 2018, among NRG Energy, Inc., the guarantors named therein and Delaware Trust Company, as trustee, containing Form of 2.750% Convertible Senior Notes due 2048.	Incorporated herein by reference to Exhibit 4.1 to the Registrant's Current Report on Form 8-K, filed on May 25, 2018.
4.15	Supplemental Indenture (Additional Subsidiary Guarantees-2.750% Convertible Senior Notes due 2048) dated January 5, 2021, among NRG Energy, Inc., each of its guarantor subsidiaries, and Delaware Trust Company as trustee.	Incorporated herein by reference to Exhibit 4.1 to the Registrant's quarterly report on Form 10-Q filed on May 6, 2021.
4.16	Supplemental Indenture (Additional Subsidiary Guarantees-2.750% Convertible Senior Notes due 2048) dated February 17, 2022, among NRG Energy, Inc., each of its guarantor subsidiaries, and Delaware Trust Company as trustee.	Incorporated herein by reference to Exhibit 4.53 to the Registrant's annual report on Form 10-K filed on February 24, 2022.
4.17	Supplemental Indenture (Settlement Elections - 2.750% Convertible Senior Notes due 2048) dated February 22, 2022, among NRG Energy, Inc., each of its guarantor subsidiaries, and Delaware Trust Company as trustee.	Incorporated herein by reference to Exhibit 4.52 to the Registrant's annual report on Form 10-K filed on February 24, 2022.
4.18	Base Indenture, dated August 29, 2023, between NRG Energy, Inc. and Deutsche Bank Trust Company Americas, as trustee, pertaining to the Alexander Funding Trust II Pre-Capitalized Trust Securities.	Incorporated herein by reference to Exhibit 4.4 to the Registrant's current report on Form 8-K filed on August 29, 2023.
4.19	Supplemental Indenture, dated August 29, 2023, among NRG Energy, Inc., the guarantors named therein and Deutsche Bank Trust Company Americas, as trustee, containing Form 7.467% Senior Secured First Lien Notes due 2028.	Incorporated herein by reference to Exhibit 4.5 to the Registrant's current report on Form 8-K filed on August 29, 2023.
4.20	Indenture, dated as of February 14, 2020, among APX Group, Inc., the guarantors party thereto and Wilmington Trust, National Association as trustee and collateral agent relating to APX Group, Inc.’s 6.75% Senior Secured Notes due 2027.	Incorporated herein by reference to Exhibit 10.1 to Vivint Smart Home, Inc.'s Current Report on Form 8-K filed on February 19, 2020).
4.21	Indenture, dated as of July 9, 2021, between APX Group, Inc., as the Issuer, the guarantors party hereto, and Wilmington Trust, National Association, as trustee, payment agent and registrar, relating to the Company's 5.75% Senior Notes due 2029.	Incorporated herein by reference to Exhibit 10.1 to Vivint Smart Home, Inc.'s Current Report on Form 8-K filed on July 12, 2021.

164

4.22	Description of NRG Energy, Inc. securities registered pursuant to section 12 of the Securities Exchange Act of 1934	Incorporated herein by reference to Exhibit 4.15 to the Registrant's Annual Report on Form 10-K, filed on February 27, 2020.
10.1*	Form of NRG Energy, Inc. Long-Term Incentive Plan Deferred Stock Unit Agreement for Directors.	Incorporated herein by reference to Exhibit 10.15 to the Registrant's annual report on Form 10-K filed on March 30, 2005.
10.2*	Form of NRG Energy, Inc. Long-Term Incentive Plan Restricted Stock Unit Agreement for Officers.	Incorporated herein by reference to Exhibit 10.6 to the Registrant's annual report on Form 10-K filed on March 1, 2018.
10.3*	Form of NRG Energy, Inc. Long-Term Incentive Plan Restricted Stock Unit Agreement for Non-Officers.	Incorporated herein by reference to Exhibit 10.7 to the Registrant's annual report on Form 10-K filed on March 1, 2018.
10.4*	Second Amended and Restated Annual Incentive Plan for Designated Corporate Officers.	Incorporated herein by reference to Exhibit 10.1 to the Registrant's current report on Form 8-K filed on May 7, 2015.
10.5*	The NRG Energy, Inc. Amended and Restated Long-Term Incentive Plan.	Incorporated herein by reference to Exhibit 10.1 to the Registrant's current report on Form 8-K filed on April 28, 2017.
10.6*	NRG 2010 Stock Plan for GenOn Employees.	Incorporated herein by reference to Exhibit 10.49 to the Registrant’s annual report on Form 10-K filed on February 27, 2013.
10.7*	Form of NRG Energy, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement for Officers.	Incorporated herein by reference to Exhibit 10.73 to the Registrant's annual report on Form 10-K filed on March 1, 2018.
10.8*	Form of NRG Energy, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement for Senior Vice Presidents.	Incorporated herein by reference to Exhibit 10.74 to the Registrant's annual report on Form 10-K filed on March 1, 2018.
10.9†	Consent and Indemnity Agreement, dated as of February 6, 2018, by and among NRG Energy, Inc., NRG Repowering Holdings LLC, NRG Yield, Inc., and GIP III Zephyr Acquisition Partners, L.P., and NRG Yield Operating LLC (solely with respect to Sections E.5, E.6 and G.12).	Incorporated herein by reference to Exhibit 10.34 to NRG Yield, Inc.'s Annual Report on Form 10-K filed on March 1, 2018.
10.10*	NRG Energy, Inc. Amended and Restated Executive Change-in-Control and General Severance Plan for Tier IA and Tier IIA Executives (Amended and Restated Effective January 1, 2024).	Filed herewith
10.11	Sixth Amendment to Second Amended and Restated Credit Agreement, dated as of February 14, 2023, by and among NRG Energy, Inc., its subsidiaries party thereto, the lenders and issuing banks party thereto, Citicorp North America, Inc., as administrative agent and collateral agent, and Deutsche Bank Trust Company Americas, as collateral trustee, and included as Exhibit A-2 thereto a clean conformed copy of the Second Amended and Restated Credit Agreement	Incorporated herein by reference to Exhibit 10.1 to the Registrant's current report on Form 8-K filed on February 15, 2023.
10.12	Seventh Amendment to Second Amended and Restated Credit Agreement, dated as of March 13, 2023, by and among NRG Energy, Inc., its subsidiaries party thereto, the lenders and issuing banks party thereto, Citicorp North America, Inc., as administrative agent and collateral agent, and Deutsche Bank Trust Company Americas, as collateral trustee.	Incorporated herein by reference to Exhibit 4.2 to the Registrant's quarterly report on Form 10-Q filed on May 4, 2023.
10.13	Second Amended and Restated Credit Agreement, dated as of July 9, 2021, among APX Group Holdings, Inc., as Holdings, APX Group, Inc., as the borrower, the guarantors party hereto from time to time, Bank of America, N.A., as administrative agent, swing line lender and an L/C issuer.	Incorporated herein by reference to Exhibit 10.2 to Vivint Smart Home, Inc.'s Current Report on Form 8-K filed on July 12, 2021.
10.14	Amendment No.1 to the Second Amended and Restated Credit Agreement, dated as of June 9, 2023, by and between AXP Group, Inc. as borrower and the Bank of America, N.A., as administrative agent.	Incorporated herein by reference to Exhibit 4.1 to the Registrant's quarterly report on Form 10-Q filed on August 8, 2023.

165

10.15	Facility Agreement, dated August 29, 2023, among NRG Energy, Inc., the guarantors party thereto, Alexander Funding Trust II and Deutsche Bank Trust Company Americas, as the notes trustee	Incorporated herein by reference to Exhibit 4.1 to the Registrant's current report on Form 8-K filed on August 29, 2023.
10.16	Letter of Credit Facility Agreement, dated August 29, 2023, among NRG Energy, Inc., the financial institutions from time to time party thereto as letter of credit issuers, and Deutsche Bank Trust Company Americas, as administrative agent and as collateral agent	Incorporated herein by reference to Exhibit 4.2 to the Registrant's current report on Form 8-K filed on August 29, 2023.
10.17	Amended and Restated Declaration of Trust of Alexander Funding Trust II, dated August 29, 2023, among NRG Energy, Inc. as depositor and in its own capacity, Deutsche Bank Trust Company Americas, as trustee, and Deutsche Bank Trust Company Delaware, as Delaware trustee	Incorporated herein by reference to Exhibit 4.3 to the Registrant's current report on Form 8-K filed on August 29, 2023.
10.18	Receivables Sale Agreement, dated as of September 22, 2020, among the Originators from time to time parties thereto, NRG Retail LLC, as Servicer, and NRG Receivables LLC.	Incorporated herein by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on September 22, 2020.
10.19	Amendment No. 3 to Receivables Loan and Servicing Agreement, dated as of June 22, 2023, among NRG Retail LLC, as Servicer, NRG Receivables LLC, as Borrower, NRG Energy, Inc., as Performance Guarantor, the Conduit Lenders, Committed Lenders, Facility Agents and LC Issuers party thereto, and Royal Bank of Canada, as administrative Agent, and included as Exhibit A-2 thereto a clean, conformed copy of the Receivables Loan and Servicing Agreement.	Incorporated herein by reference to Exhibit 10.1 to the Registrant's current report on Form 8-K filed on June 27, 2023.
10.20*	Form of NRG Energy, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement for Chief Executive Officer	Incorporated herein by reference to Exhibit 10.21 to the Registrant's annual report on Form 10-K filed on February 24, 2022.
10.21*	Form of NRG Energy, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement for Executive Vice Presidents	Incorporated herein by reference to Exhibit 10.22 to the Registrant's annual report on Form 10-K filed on February 24, 2022.
10.22*	Form of NRG Energy, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement for Senior Vice Presidents.	Incorporated herein by reference to Exhibit 10.23 to the Registrant's annual report on Form 10-K filed on February 24, 2022.
10.23*	Form of NRG Energy, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement for Senior Vice Presidents.	Filed herewith
10.24*	Form of NRG Energy, Inc. Long-Term Incentive Plan Restricted Stock Unit Agreement.	Filed herewith
10.25*	Restricted Stock Unit Agreement, dated December 15, 2023, between NRG Energy, Inc. and Lawrence S. Coben	Filed herewith
10.26*	Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan	Incorporated herein by reference to Exhibit 4.4 to Vivint Smart Home's Post-Effective Amendment on Form S-8 to Registration Statement on Form S-4 filed with the Securities and Exchange Commission on March 24, 2020
10.27*	Vivint Smart Home, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement and Notice of Grant under the Vivint Smart Home, Inc. Omnibus Incentive Plan.	Incorporated herein by reference to Exhibit 10.2 to the Registrant's quarterly report on Form 10-Q filed on May 4, 2023.
10.28*	Vivint Smart Home, Inc. Long-Term Incentive Plan Restricted Stock Unit Agreement and Notice of Grant under the Vivint Smart Home, Inc. Omnibus Incentive Plan.	Incorporated herein by reference to Exhibit 10.3 to the Registrant's quarterly report on Form 10-Q filed on May 4, 2023.
10.29*	Vivint Smart Home, Inc. Long-Term Incentive Plan Relative Performance Stock Unit Agreement and Notice of Grant under the Vivint Smart Home, Inc. Omnibus Incentive Plan for Executive Vice President	Filed herewith
10.30*	Vivint Smart Home, Inc. Long-Term Incentive Plan Restricted Stock Unit Agreement and Notice of Grant under the Vivint Smart Home, Inc. Omnibus Incentive Plan for Executive Vice Presidents.	Filed herewith

166

10.31*	Amended and Restated Employee Stock Purchase Plan	Incorporated herein by reference to Exhibit 10.1 to the Registrant's current report on Form 8-K filed on May 2, 2023.
10.32*	Retention letter, dated December 6, 2022, between Vivint Smart Home, Inc. and Rasesh Patel.	Incorporated herein by reference to Exhibit 10.45 to Vivint Smart Home, Inc.'s Annual Report on Form 10-K for the annual period ended December 31, 2022.
10.33*	Amended and Restated Employment Agreement, dated June 20, 2022, between Vivint Smart Home, Inc. and Rasesh Patel	Incorporated by reference to Exhibit 10.5 to Vivint Smart Home, Inc.'s Quarterly Report on Form 10-Q for the quarter ended June 30, 2022
10.34*	Amendment to the Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan	Incorporated herein by reference to Exhibit 10.1 to the Registrant's quarterly report on Form 10-Q filed on August 8, 2023.
10.35	Cooperation Agreement, dated as of November 20, 2023, by and among NRG Energy, Inc., Elliott Investment Management L.P., Elliott Associates, L.P., and Elliott International, L.P.	Incorporated herein by reference to Exhibit 10.1 to the Registrant’s current report on Form 8-K filed on November 20, 2023
21.1	Subsidiaries of NRG Energy, Inc.	Filed herewith.
22.1	List of Guarantor Subsidiaries	Filed herewith.
23.1	Consent of KPMG LLP.	Filed herewith.
24.1	Power of Attorney	Included on signature page
31.1	Rule 13a-14(a)/15d-14(a) certification of Lawrence Coben	Filed herewith.
31.2	Rule 13a-14(a)/15d-14(a) certification of Woo-Sung Chung	Filed herewith.
31.3	Rule 13a-14(a)/15d-14(a) certification of G. Alfred Spencer	Filed herewith.
32	Section 1350 Certification.	Furnished herewith.
97	NRG Energy, Inc. Clawback Policy	Filed herewith.
101 INS	Inline XBRL Instance Document.	The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.
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 it's Inline XBRL tags are embedded within the Inline XBRL document).	Filed herewith.

*	Exhibit relates to compensation arrangements.
†	Portions of this exhibit have been redacted and are subject to a confidential treatment request filed with the Secretary of the Securities and Exchange Commission pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended.
^	This filing excludes schedules pursuant to Item 601(b)(2) of Regulation S-K, which the registrant agrees to furnish supplementary to the Securities and Exchange Commission upon request by the Commission.
‡	Portions of this exhibit have been excluded because they are both not material and would likely cause competitive harm to the registrant if publicly disclosed. Information that has been omitted has been noted in this document with a placeholder identified by the mark “[***]”.

Item 16. Form 10-K Summary

None.

167

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.

NRG ENERGY, INC. (Registrant)
By:	/s/ LAWRENCE S. COBEN
	Lawrence S. Coben Interim President and Chief Executive Officer

Date: February 28, 2024

168

POWER OF ATTORNEY

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

In accordance with the Exchange Act, this report has been signed by the following persons on behalf of the registrant in the capacities indicated on February 28, 2024.

Signature	Title	Date
/s/ LAWRENCE S. COBEN	Interim President and Chief Executive Officer and	February 28, 2024
Lawrence S. Coben	Director (Principal Executive Officer, Chair of the Board)
/s/ WOO-SUNG CHUNG	Chief Financial Officer	February 28, 2024
Woo-Sung Chung	(Principal Financial Officer)
/s/ G. ALFRED SPENCER	Chief Accounting Officer	February 28, 2024
G. Alfred Spencer	(Principal Accounting Officer)
/s/ E. SPENCER ABRAHAM	Director	February 28, 2024
E. Spencer Abraham
/s/ ANTONIO CARRILLO	Director	February 28, 2024
Antonio Carrillo
/s/ MATTHEW CARTER, JR.	Director	February 28, 2024
Matthew Carter, Jr.
/s/ HEATHER COX	Director	February 28, 2024
Heather Cox
/s/ ELISABETH B. DONOHUE	Director	February 28, 2024
Elisabeth B. Donohue
/s/ MARWAN FAWAZ	Director	February 28, 2024
Marwan Fawaz
/s/ PAUL W. HOBBY	Director	February 28, 2024
Paul W. Hobby
/s/ ALEX POURBAIX	Director	February 28, 2024
Alex Pourbaix
/s/ ALEXANDRA PRUNER	Director	February 28, 2024
Alexandra Pruner
/s/ ANNE C. SCHAUMBURG	Director	February 28, 2024
Anne C. Schaumburg
/s/ MARCIE C. ZLOTNIK	Director	February 28, 2024
Marcie C. Zlotnik

169

EX-2.7

Exhibit 2.7

AMENDMENT NO. 1 TO
EQUITY PURCHASE AGREEMENT

This AMENDMENT NO. 1 TO EQUITY PURCHASE AGREEMENT (this “Amendment”), dated as of September 29, 2023, is entered into by and among Constellation Energy Generation, LLC, a Pennsylvania limited liability company (“Buyer”), Texas Genco GP, LLC a Texas limited liability company (“Texas Genco GP”), and Texas Genco LP, LLC, a Delaware limited liability company (“Texas Genco LP”, and together with Texas Genco GP, the “Seller”). Capitalized terms used but not otherwise defined herein shall have the respective meanings assigned to such terms in the Purchase Agreement (as defined below).

RECITALS

WHEREAS, Buyer and Seller entered into that certain Equity Purchase Agreement, dated as of May 31, 2023 (the “Purchase Agreement”), pursuant to which, among other things, Buyer agreed to purchase from Seller and Seller agreed to sell to Buyer all of the Equity in and to NRG South Texas LP, in accordance with the terms of the Purchase Agreement; and

WHEREAS, in accordance with Section 13.1 of the Purchase Agreement, Buyer and Seller desire to enter into this Amendment in order to amend the terms of the Purchase Agreement as set forth herein.

NOW, THEREFORE, for and in consideration of the promises and the mutual covenants contained herein, and for other good and valuable consideration, the receipt, adequacy and legal sufficiency of which are hereby acknowledged, the parties hereto hereby agree as follows:

AGREEMENT

1.Amendment to Section 1.1. The defined terms “Closing Effective Time”, “QSE Agreements” and “QSE Assignment” in Section 1.1 of the Purchase Agreement are hereby amended and restated in their entirety as follows:

“Closing Effective Time” means 11:59 p.m. local time in Houston, Texas on the Closing Date; provided, however, that, if the Closing Date is the first day of a calendar month, the Closing Effective Time shall mean 12:01 a.m. local time in Houston, Texas on the Closing Date.

“QSE Agreements” means (a) the Amended Agreement for Master Qualified Scheduling Entity Services, effective as of May 19, 2005, by and among San Antonio, Austin, the Company and the QSE (as successor in interest to Texas Genco II, LP), (b) the Nuclear Plant Interface Agreement, effective as of April 1, 2010, by and between STPNOC and QSE, and (c) the Meter Splitting Agreement (for Jointly Owned Generation) with the QSE (as successor in interest to Texas Genco II, LP), as Applicant and Master QSE and signed by the Company (as successor in interest to Texas Genco, LP), San Antonio and Austin attached to the Notice of Change of Information dated effective as of May 19, 2005.

“QSE Assignment” means the QSE Agreement, dated as of September 29, 2023, between the QSE and Buyer providing that (a) the QSE shall continue to perform under the QSE Agreements with respect to the Company, STPNOC, San Antonio and Austin, and (b) the QSE shall cooperate in good faith with Buyer, STPNOC and the Company to transition timely and orderly the services provided under the QSE Agreements.

2.Amendment to Section 6.8(b). Section 6.8(b) of the Purchase Agreement is hereby amended and restated in its entirety as follows:

        “(b)    As of the date thereof, the QSE Assignment has been executed and delivered by the parties thereto.”

3.Amendment to Section 10.2(e)(i)(C). Section 10.2(e)(i)(C) of the Purchase Agreement is hereby amended and restated in its entirety as follows:

“(C)    the QSE Assignment, duly executed by the QSE;”

4.Amendment to Section 10.2(e)(ii)(D). Section 10.2(e)(ii)(D) of the Purchase Agreement is hereby amended and restated in its entirety as follows:

“(D)    the QSE Assignment, duly executed by the Buyer;”

5.References to and Effect on the Purchase Agreement. Except as expressly amended by this Amendment, all of the terms, conditions, and other provisions of the Purchase Agreement shall continue to be in force and effect in accordance with their respective terms. No reference to this Amendment need be made in any instrument or document making reference to the Purchase Agreement, and any reference to the Purchase Agreement in any such instrument or document shall be deemed to refer to the Purchase Agreement as amended by this Amendment.

6.Miscellaneous. Article XIII (Miscellaneous) of the Purchase Agreement shall apply to this Amendment to the same extent as if set forth herein, mutatis mutandis.

(signatures follow)

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IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be duly executed on the day and year first above written.

CONSTELLATION ENERGY GENERATION, LLC

By:

Name: David O. Dardis

Title: Executive Vice President, Chief Legal Officer
and General Counsel

Signature Page to Amendment No. 1 to Equity Purchase Agreement

TEXAS GENCO GP, LLC

By:

Name: Dudley D. Zahn

Title: Vice President

TEXAS GENCO LP, LLC

By:

Name: Dudley D. Zahn

Title: Vice President

Signature Page to Amendment No. 1 to Equity Purchase Agreement

EX-2.8

Exhibit 2.8

AMENDMENT NO. 2 TO
EQUITY PURCHASE AGREEMENT

This AMENDMENT NO. 2 TO EQUITY PURCHASE AGREEMENT (this “Amendment”), dated as of November 1, 2023, is entered into by and among Constellation Energy Generation, LLC, a Pennsylvania limited liability company (“Buyer”), Texas Genco GP, LLC a Texas limited liability company (“Texas Genco GP”), and Texas Genco LP, LLC, a Delaware limited liability company (“Texas Genco LP”, and together with Texas Genco GP, the “Seller”). Capitalized terms used but not otherwise defined herein shall have the respective meanings assigned to such terms in the Purchase Agreement (as defined below).

RECITALS

WHEREAS, Buyer and Seller entered into that certain Equity Purchase Agreement, dated as of May 31, 2023 as amended by that certain Amendment No. 1 dated as of September 29, 2023 (the “Purchase Agreement”), pursuant to which, among other things, Buyer agreed to purchase from Seller and Seller agreed to sell to Buyer all of the Equity in and to NRG South Texas LP, in accordance with the terms of the Purchase Agreement; and

WHEREAS, in accordance with Section 13.1 of the Purchase Agreement, Buyer and Seller desire to enter into this Amendment in order to amend the terms of the Purchase Agreement as set forth herein.

NOW, THEREFORE, for and in consideration of the promises and the mutual covenants contained herein, and for other good and valuable consideration, the receipt, adequacy and legal sufficiency of which are hereby acknowledged, the parties hereto hereby agree as follows:

AGREEMENT

1.Amendment to Section 1.1. Section 1.1 of the Purchase Agreement is hereby amended to add the following defined terms:

(a)“Nuclear Decommissioning Liabilities” means all liabilities relating to the Facility that are applicable to the retirement of a nuclear power plant, which will include the retirement, dismantlement, removal and decontamination of the Facility, and any storage, reduction or removal, whether before or after termination of the NRC Licenses for the Facility, of nuclear materials at the site of the facility.

(b)“Private Letter Ruling” means any Qualified Decommissioning Fund Status Ruling or Transfer Private Letter Ruling.

(c)“QDF Controlling Party” means (a) in the case of any Private Letter Ruling, Private Letter Ruling Request or Tax Proceeding of or with respect to any Qualified Decommissioning Fund for any Pre-Closing Tax Period, Seller, e.g., Seller’s Transfer Private Letter Ruling request and the Qualified Decommissioning Fund Status Ruling request; and (b) in the case of any Private Letter Ruling, Private Letter Ruling Request or Tax Proceeding of or with respect to any Qualified Decommissioning Fund for any Post-Closing Tax Period or Straddle Period, Buyer (e.g., Buyer’s Transfer Private Letter Ruling request).

(d)“QDF Non-Controlling Party” means whichever of Seller or Buyer is not the Controlling Party with respect to any Private Letter Ruling or Private Letter Ruling Request.

(e)“Qualified Decommissioning Fund Representations” means the representations and warranties set forth in Section 3.16 of the Purchase Agreement.

(f)“Qualified Decommissioning Fund Status Ruling” means a private letter ruling or rulings from the IRS pursuant to Treasury Regulation Section 301.9100-1 et seq. necessary or appropriate to cause each Qualified Decommissioning Fund to satisfy the conditions specified in Section 3.16(a).

(g)“Transfer Private Letter Ruling” means a private letter ruling from the IRS that (a)(i) each Qualified Decommissioning Fund will not be “disqualified” (within the meaning of Treasury

Regulation 1.468A- 5(c)) by reason of the deemed transfer of such Qualified Decommissioning Fund; (ii) each Qualified Decommissioning Fund will continue to be treated as satisfying the requirements of Section 468A of the Code and Treasury Regulation Section 1.468A-5 following the deemed transfer of such Qualified Decommissioning Fund; (iii) each Qualified Decommissioning Fund will not recognize gain or loss by reason of the deemed transfer of such Qualified Decommissioning Fund; (iv) neither Seller nor Buyer will recognize gain or loss by reason of the deemed transfer of any Qualified Decommissioning Fund; and (v) the tax basis of each Qualified Decommissioning Fund in its assets will not change by reason of the deemed transfer of such Qualified Decommissioning Fund; and (b) in the case of Seller, (i) Seller’s amount realized from the Contemplated Transactions will include the excess of the Nuclear Decommissioning Liabilities associated with the Facility (if any) over the value of the Qualified Decommissioning Funds on the date of the purchase and sale of the Equity of the Company; and (ii) to the extent of the amount of the Nuclear Decommissioning Liabilities that are included in Seller’s amount realized from the sale of the Equity of the Company, Seller will be entitled to treat that portion of the Nuclear Decommissioning Liabilities as satisfying the economic performance requirements under Treasury Regulation Section 1.461-4(d)(5).

2.Amendment to Section 6.16. Section 6.16 of the Purchase Agreement is hereby amended and restated in its entirety to read as follows:

Section 6.16    Certain Agreements regarding the Qualified Decommissioning Funds.

(a)    Subject to and without limiting Seller’s obligations under Section 3.16 and Section 6.16 (b) through (e) below,following the Closing, Buyer agrees to (and, as applicable, agrees to cause the Company, any relevant Buyer Affiliate or the QNDT Trustee to) maintain each Qualified Decommissioning Fund in accordance with all applicable Nuclear Laws, the Decommissioning Trust Agreement, and Sections 468A and 4951 of the Code and the Treasury Regulations promulgated thereunder (including any prohibitions on self-dealing (as defined in Section 468A(e)(5) of the Code and Treasury Regulation Section 1.468A-5(b)(2))), in order to ensure that each Qualified Decommissioning Fund will be treated as a nuclear decommissioning fund (as defined in Treasury Regulation Sections 1.468A-1(b)(4) and 1.468A-5) until the ultimate termination of the Section 468A “qualified” status of each Qualified Decommissioning Fund upon substantial completion (as defined by Treasury Regulation Section 1.468A-5(d)) of the Decommissioning of the Facility.

(b)    Seller acknowledges that if any “excess contribution” (as defined in Section 1.468A-5(c)(2)(ii) of the Treasury Regulations) was made to either Qualified Decommissioning Fund which has not been withdrawn within the period provided under Section 1.468A-5(c)(2)(i) of the Treasury Regulations (“Excess Contribution”), such Excess Contribution would constitute a breach of the Qualified Decommissioning Fund Representations. Seller further acknowledges that any amounts payable to the IRS by the Company, Buyer, its Affiliates, or any of the Qualified Decommissioning Funds as a result of such Excess Contributions, including any Taxes, interest or penalties, and any other detrimental Tax effect on Buyer, its Affiliates or any Qualified Decommissioning Fund as a result of such Excess Contributions (including, but not limited to, a reduction in the amount of the Purchase Price allocable to either the Qualified Nuclear Decommissioning Funds or the Facility) constitute Seller Indemnified Taxes.

(c)    Following the Closing, Buyer and Seller shall cooperate in good faith and use their respective Reasonable Efforts to diligently pursue and obtain all applicable Private Letter Rulings from the IRS, including promptly filing any applications, requests, notices or other documentation with the IRS or any other Governmental Entity (“Private Letter Ruling Request”).

(d)    With respect to any Private Letter Ruling Request, (i) the QDF Controlling Party shall consult with the QDF Non-Controlling Party and offer the QDF Non-Controlling Party a reasonable opportunity to comment before submitting any material written correspondence or other documents prepared or furnished in connection with such Private Letter Ruling Request, which comments the QDF Controlling Party shall consider in good faith; (ii) the QDF Controlling Party shall pursue such Private Letter Ruling Request diligently and in good faith; (iii) the QDF Non-Controlling Party shall be entitled to participate in any material telephone calls, conferences or other meetings with the IRS in connection with such Private Letter Ruling Request and the QDF

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Controlling Party shall use Reasonable Efforts to permit the QDF Non-Controlling Party to participate in any such calls, conferences or meetings; and (iv) the QDF Controlling Party shall not settle, compromise, abandon or withdraw any such Private Letter Ruling Request without obtaining the prior written consent of the QDF Non-Controlling Party, which consent shall not be unreasonably withheld, conditioned or delayed, provided that the QDF Controlling Party shall not have any obligations to the QDF Non-Controlling Party with respect to any portion of any such Private Letter Ruling Request (and any actions, written materials, meetings or conferences relating exclusively thereto) that could not reasonably be expected to affect the liability of, or otherwise have an adverse effect on, the QDF Non-Controlling Party, any of its Affiliates, or any Qualified Decommissioning Fund.

(e)    Seller shall before Closing determine the amount of the Excess Contributions and the earnings thereon (the “Excess Contribution Amount”). With respect to Excess Contributions attributable to the 2023 tax year, Seller shall before Closing transfer or cause to be transferred such Excess Contributions and the earning thereon from the applicable Qualified Decommissioning Fund to each respective Facility’s non-qualified nuclear decommissioning fund. With respect to Excess Contributions attributable to all tax years prior to 2023, Buyer shall, promptly after receiving a favorable Qualified Decommissioning Fund Status Ruling, transfer or cause to be transferred such Excess Contributions and, if required by the Qualified Decommissioning Fund Status Ruling, the earnings thereon, from the applicable Qualified Decommissioning Fund to each respective Facility’s non-qualified nuclear decommissioning fund. For the avoidance of doubt, the provisions of this paragraph (e) do not limit the provisions of paragraph (b) above.

(f)    In the case of a Tax Proceeding of or with respect to any Qualified Decommissioning Fund (in each case, other than a Tax Proceeding described in Section 7.4(c)), the QDF Controlling Party shall have the right and obligation to conduct, at its own expense, such Tax Proceeding; provided, however, that (i) the QDF Controlling Party shall provide the QDF Non-Controlling Party with a timely and reasonably detailed account of each stage of such Tax Proceeding, (ii) the QDF Controlling Party shall consult with the QDF Non-Controlling Party before taking any significant action in connection with such Tax Proceeding, (iii) the QDF Controlling Party shall consult with the QDF Non-Controlling Party and offer the QDF Non-Controlling Party an opportunity to comment before submitting any written materials prepared or furnished in connection with such Tax Proceeding, (iv) the QDF Controlling Party shall defend such Tax Proceeding diligently and in good faith, (v) the QDF Non-Controlling Party shall be entitled to participate in such Tax Proceeding, and (vi) the QDF Controlling Party shall not settle, compromise or abandon any such Tax Proceeding without obtaining the prior written consent of the Non-Controlling Party, which consent shall not be unreasonably withheld, conditioned or delayed; provided further that the QDF Controlling Party shall not have any obligations to the QDF Non-Controlling Party under the immediately foregoing proviso with respect to any portion of such Tax Proceeding (and any actions, written materials, meetings or conferences relating exclusively thereto) that would not reasonably be expected to affect the liability of, or otherwise have an adverse effect on, the QDF Non-Controlling Party, any of its Affiliates or any Qualified Decommissioning Fund.In the event of any conflict or overlap between the provisions of this Section 6.16(f) and Section 12.2, this Section 6.16(f) shall control.

(g)    Notwithstanding anything herein to the contrary, Seller’s indemnification obligations under Article XII shall be reduced to take into account any Tax benefit (whether by refund, overpayment, credit, reduction in Taxes otherwise payable or otherwise) that has been realized by any Buyer Indemnified Party arising from or is attributable to (i) the incurrence of any Adverse Consequence incurred by Buyer Indemnified Parties with respect to any breach of any Qualified Decommissioning Fund Representation or any Seller Indemnified Tax relating thereto; or (ii) any contributions (up to the Excess Contribution Amount) made by or on behalf of any Buyer Indemnified Party to either Qualified Decommissioning Fund that are allowed as a result of the withdrawal of the Excess Contributions from the Qualified Decommissioning Funds; provided, that, if any such Tax benefit is realized after an indemnification payment is made by Seller, such Buyer Indemnified Party shall, within fifteen (15) days of the realization of such Tax benefit, pay to Seller an amount in cash equal to such Tax benefit. The amount of any such Tax benefit shall be

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determined (A) using the maximum statutory rate then in effect for applicable federal Taxes, and (B) for state and local Taxes (if applicable), using the maximum combined state and local rate then in effect, which will be Tax effected at such maximum federal rate.

3.References to and Effect on the Purchase Agreement. Except as expressly amended by this Amendment, all of the terms, conditions, and other provisions of the Purchase Agreement shall continue to be in force and effect in accordance with their respective terms. No reference to this Amendment need be made in any instrument or document making reference to the Purchase Agreement, and any reference to the Purchase Agreement in any such instrument or document shall be deemed to refer to the Purchase Agreement as amended by this Amendment.

4.Miscellaneous. Article XIII (Miscellaneous) of the Purchase Agreement shall apply to this Amendment to the same extent as if set forth herein, mutatis mutandis.

(signatures follow)

4

IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be duly executed on the day and year first above written.

CONSTELLATION ENERGY GENERATION, LLC

By:

Name:

Title:

Signature Page to Amendment No. 2 to Equity Purchase Agreement

TEXAS GENCO GP, LLC

By:

Name:

Title:

TEXAS GENCO LP, LLC

By:

Name:

Title:

Signature Page to Amendment No. 2 to Equity Purchase Agreement

EX-2.9

Exhibit 2.9

AMENDMENT NO. 3 TO
EQUITY PURCHASE AGREEMENT

This AMENDMENT NO. 3 TO EQUITY PURCHASE AGREEMENT (this “Amendment”), dated as of November 1, 2023, is entered into by and among Constellation Energy Generation, LLC, a Pennsylvania limited liability company (“Buyer”), Texas Genco GP, LLC, a Texas limited liability company (“Texas Genco GP”), and Texas Genco LP, LLC, a Delaware limited liability company (“Texas Genco LP”, and together with Texas Genco GP, the “Seller”). Capitalized terms used but not otherwise defined herein shall have the respective meanings assigned to such terms in the Purchase Agreement (as defined below).

RECITALS

WHEREAS, Buyer and Seller entered into that certain Equity Purchase Agreement, dated as of May 31, 2023, as amended by that certain Amendment No. 1 dated as of September 29, 2023, as further amended by that certain Amendment No. 2 dated as of November 1, 2023 (the “Purchase Agreement”), pursuant to which, among other things, Buyer agreed to purchase from Seller and Seller agreed to sell to Buyer all of the Equity in and to NRG South Texas LP (the “Company”), in accordance with the terms of the Purchase Agreement;

WHEREAS, on June 20, 2023, San Antonio filed the Lawsuit described below, which Austin later joined, related to the transaction contemplated by the Purchase Agreement;

WHEREAS, on July 31, 2023, Buyer filed its Original Petition in Intervention in the Lawsuit;

WHEREAS, Buyer and San Antonio and Buyer and Austin are engaged in settlement discussions with respect to the claims brought by San Antonio and Austin pursuant to the Lawsuit; and

WHEREAS, in accordance with Section 13.1 of the Purchase Agreement, Buyer and Seller desire to enter into this Amendment in order to amend the terms of the Purchase Agreement as set forth herein;

NOW, THEREFORE, for and in consideration of the promises and the mutual covenants contained herein, and for other good and valuable consideration, the receipt, adequacy and legal sufficiency of which are hereby acknowledged, the parties hereto hereby agree as follows:

AGREEMENT

1.Amendment to Section 1.1. Section 1.1 of the Purchase Agreement is hereby amended to add the following defined terms where alphabetically appropriate:

“2007 Supplemental Agreement” means that certain South Texas Project Supplemental Agreement dated as of October 29, 2007 by and between San Antonio and the Company.

“2010 Settlement Agreement” means that certain Project Agreement, Settlement Agreement and Mutual Release dated as of March 1, 2010 by and among San Antonio, Nuclear Innovation North America LLC, Nina Texas 3 LLC, NINA Texas 4 LLC with joinders therein by Company and NRG Energy, Inc.

“2018 Settlement Agreement” means that certain Assignment and Assumption Agreement and Mutual Release dated as of October 1, 2018 by and among Nina Texas 3 LLC, NINA Texas 4 LLC, Company, San Antonio and Austin.

“Buyer Seller Released Claims” has the meaning specified in the definition of Buyer Seller Release.

“Buyer Seller Release” means a mutual release stating substantially the following, adapted to the defined terms of the mutual release: “Each Partyon their own behalf, and on behalf of their representatives, beneficiaries, successors, assigns and affiliates

(collectively, the “Releasors”), hereby FOREVER RELEASES, ACQUITS AND DISCHARGES the other Party, and its affiliates, and its and their respective shareholders, members, investors, directors, managers, officers, employees, insurers, agents, and attorneys (for the purposes of this definition, the “Released Parties”), of and from any and all claims, demands, actions, causes of action, liabilities, damages, expenses, costs, duties, and obligations of every kind and character whatsoever, known or unknown, which any of the Releasors ever had or now have, or may hereafter have or acquire, with respect to the following claims (the “Buyer Seller Released Claims”): (a) claims of the Releasors arising out of or relating to the Lawsuit or the subject matter thereof, and (b) solely to the extent Buyer is released from such a claim of San Antonio or Austin in any settlement or release with San Antonio or Austin related to the Lawsuit, any resulting corresponding claims of Releasors against the Released Parties which arise out of or in any way relate, directly or indirectly, to any right of refusal or pre-emptive right not described in the Lawsuit or any Lien on the Equity Interests or the Facility arising under or relating to the Participation Agreement, the 2007 Supplemental Agreement, the 2010 Settlement Agreement or the 2018 Settlement Agreement. To the extent of any Buyer Seller Released Claims, neither Party shall make any claim, including any claim for indemnification, under the Purchase Agreement with respect thereto. Notwithstanding the foregoing, this release of Buyer Seller Released Claims shall not release the Released Parties from any other claims or obligations under this Agreement or the Related Agreements or any other contractual obligations under any other agreements between Seller and its Affiliates (excluding the Company), on one hand, and Buyer and its Affiliates (including the Company), on the other.”

“Constellation South Texas” means the Company, a Texas limited partnership, which upon Closing shall be converted to a Texas limited liability company, which upon conversion shall be named “Constellation South Texas LLC”, or any other successor entity to the Company, as applicable.

“Lawsuit” means the action by San Antonio filed on June 20, 2023, and later joined by Austin, against the Company, Texas Genco GP, Texas Genco LP, and NRG Energy, Inc., under Cause No. 23-F-0279 in the 130th Judicial District Court of Matagorda County, Texas, asserting causes of action including breach of contract, specific performance and asking for declaratory judgment with respect to certain claimed rights of first refusal.

“Lawsuit Indemnity Claim” has the meaning set forth in Section 2.3(b).

“Lawsuit Settlement of San Antonio with Prejudice” means a fully executed written settlement agreement among Constellation South Texas, Buyer and San Antonio, releasing Constellation South Texas, Buyer, Seller and their respective Affiliates from all claims of San Antonio in the Lawsuit and resulting in the dismissal with prejudice of all claims by San Antonio in the Lawsuit, on terms and conditions and under documentation satisfactory to Buyer in its sole and absolute discretion.

“Property Tax Holdback” means an amount equal to the Property Tax Holdback set forth on Schedule 1.1, which is being withheld from the Estimated Purchase Price for application to the obligations of Seller under Section 7.1.

“Retained Amount” has the meaning set forth in Section 2.3(b).

“Retention Adjustment” means an amount equal to the Retention Adjustment set forth on Schedule 1.1.

“Retention End Date” has the meaning set forth in Section 2.3(b).

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2.Amendment to Section 2.1. Section 2.1(b) of the Purchase Agreement is hereby amended and restated in its entirety as follows:

“(b)     Purchase Price. The consideration to be paid for the Equity (the “Purchase Price”) shall be an amount equal to (i) One Billion Seven Hundred Fifty Million dollars ($1,750,000,000) (the “Unadjusted Purchase Price”) plus (ii) the STPNOC Prepayments Adjustment minus (iii) the STPNOC Receivables Adjustment, subject to Section 2.3. The Estimated Purchase Price, as adjusted by Section 2.3, and less the Property Tax Holdback, shall be paid at Closing by wire transfer of immediately available funds to an account designated by Seller. For the avoidance of doubt, (i) Seller Indemnified Taxes shall be determined net of any Taxes that are taken into account in the determination of the Final Purchase Price and (ii) if the Property Tax Holdback exceeds or is less than the amount of property Taxes of the Company payable with respect to the Pre-Closing Tax Period, Buyer or Seller shall pay an amount equal to such excess or shortfall by wire transfer of immediately available funds to the account designated by Seller or Buyer, within two (2) days of filing the relevant Tax Return that reflects such Tax. Seller shall provide wire instructions to Buyer at least five (5) Business Days prior to the Closing.”

3.Amendment to Schedule 1.1. Schedule 1.1 of the Purchase Agreement is hereby amended and restated in its entirety as set forth on Schedule 1.1 hereto.

4.Addition of Section 2.3. A new Section 2.3 of the Purchase Agreement is hereby added as follows:

“Section 2.3    Treatment of Lawsuit; Retention Adjustment.

        (a)    Buyer is currently negotiating to achieve Lawsuit Settlement of San Antonio with Prejudice, but is under no obligation to achieve Lawsuit Settlement of San Antonio with Prejudice or any other settlement of the Lawsuit. The Parties hereby agree and acknowledge that the Amended & Restated Consent and Non-Waiver Agreement dated as of September 1, 2023, among Buyer, NRG Energy, Inc., Texas Genco GP, Texas Genco LP, and the Company shall be deemed to be terminated effective as of Closing, without any liability to any party thereto. Following the Closing, (i) Buyer and its Affiliates, and Seller and its Affiliates, in each case may engage in any communications, discussions or negotiations or, subject to the limitations herein, enter into any agreements with San Antonio or Austin or any of their representatives as Buyer and its Affiliates, on one hand, or Seller and its Affiliates, on the other, may elect with respect to the Lawsuit and the subject matter thereof, and (ii) each Party shall use commercially reasonable efforts to keep each other Party apprised of the material substance of their communications, discussions and agreements with San Antonio or Austin, with respect to the Lawsuit and the subject matter thereof; provided, however, that (x) the right to such communications, discussions, negotiations and agreements, and appraisals, shall not limit the obligations of the Parties with respect to the Lawsuit and the subject matter thereof under this Agreement and the Related Agreements and (y) accordingly, the Parties and their Affiliates will not argue or contend in any subsequent litigation regarding Lawsuit Indemnity Claims, as defined below, that such communications, discussions, negotiations and agreements, and appraisals, waive, impair or otherwise modify in any way Buyer’s or Seller’s available rights and remedies under this Agreement, including without limitation the representations and warranties hereunder or entitlement to, or the type of available, indemnities and damages hereunder.

        (b)    Further, (i) Seller hereby acknowledges Buyer’s assertion of a claim for indemnification, upon Closing, under Sections 12.1(a) and 12.2, with respect to the Lawsuit and the subject matter thereof and Seller’s alleged breaches of this Agreement with respect thereto (the “Lawsuit Indemnity Claim”); (ii) Seller on its behalf and on behalf of NRG Energy, Inc., agrees and acknowledges that the foregoing notice shall

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constitute sufficient and timely notice of such Lawsuit Indemnity Claim for purposes of this Agreement and that certain Guaranty, dated effective as of May 31, 2023, by and between NRG Energy, Inc. and Buyer; (iii) each Party agrees that it and its Affiliates will not commence or pursue any action, claim or litigation of any kind against the other Party or its Affiliates with respect to the Lawsuit Indemnity Claim after the Retention End Date; and (iv) the Parties agree that nothing in this Section 2.3 shall in any way constitute an acknowledgement or admission by Seller that (x) there has been any breach of any representation or warranty or covenant or agreement of Seller or (y) Buyer has an indemnifiable claim under this Agreement. Seller agrees that Buyer may assume the defense against the Lawsuit effective as of the Closing solely with respect to the Company and Buyer, and shall have full control of such defense and proceedings with respect to the Company and Buyer, including any settlement thereof, provided, however, that neither Party shall settle the Lawsuit claims of San Antonio or Austin without the consent of the other, which consent shall not be unreasonably withheld. For the avoidance of doubt and notwithstanding the foregoing, Seller shall retain the right to settle the Lawsuit without consent of Buyer on its own behalf and behalf of its Affiliates, excluding Company, provided such settlement shall not materially prejudice Buyer or its Affiliates in the Lawsuit. Buyer agrees it will pay the full cost and expense associated with its defense of the claims in the Lawsuit, unless the Lawsuit Settlement of San Antonio with Prejudice has not occurred by the Retention End Date in which case the provisions of Section 2.3(c)(ii) shall control. Seller hereby consents to any settlement of the Lawsuit claims of San Antonio by Buyer that constitutes a Lawsuit Settlement of San Antonio with Prejudice provided that (i) Buyer shall have delivered the Buyer Seller Release to Seller and (ii) the Retention End Date shall yet not have occurred. The Parties agree that in the event of a conflict between the provisions of Section 12.2 and this Section 2.3, this Section 2.3 shall control.

(c)    Pending an anticipated Lawsuit Settlement of San Antonio with Prejudice, an amount equal to the Retention Adjustment (the “Retained Amount”) shall be withheld by Buyer from the Estimated Purchase Price payable by Buyer at Closing and retained by Buyer for application as contemplated by Section 2.3(c)(i) below until the earlier of November 1, 2024, or ten (10) Business Days after receipt by Seller of prompt written notice from Buyer stating Buyer cannot achieve Lawsuit Settlement of San Antonio with Prejudice on terms materially equal to or better than those provided by Buyer to Seller in connection with this Section 2.3 (such earlier date, the “Retention End Date”).

(i)    If Buyer enters into a settlement or release with San Antonio before the Retention End Date, such settlement or release must be a Lawsuit Settlement of San Antonio with Prejudice, and Buyer shall deliver to Seller both of the Lawsuit Settlement of San Antonio with Prejudice and the Buyer Seller Release. Upon the delivery of the Lawsuit Settlement of San Antonio with Prejudice and the Buyer Seller Release before the Retention End Date, (A) the Purchase Price shall be reduced by the Retention Adjustment and Buyer shall permanently retain the Retained Amount and (B) upon Seller’s execution and delivery of the Buyer Seller Release, Seller shall have no obligations under Sections 12.1(a) and 12.2 with respect to the Buyer Seller Released Claims.

(ii)    If, on the Retention End Date, Buyer has not delivered to Seller the Lawsuit Settlement of San Antonio with Prejudice and the Buyer Seller Release, there shall be no Retention Adjustment to the Purchase Price and Buyer shall pay to Seller the Retained Amount on the Retention End Date by wire transfer of immediately available funds to the account designated by Seller, and each Party shall retain and be entitled to pursue all rights and remedies that such Party may have against each other Party and their Affiliates pursuant to this Agreement and the Related Agreements, and neither Party shall have been deemed to have waived or relinquished any rights or obligations under this Agreement by virtue of this Section 2.3 or the actions contemplated hereunder. Notwithstanding

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anything in this Agreement contained herein to the contrary, after the Retention End Date, Buyer shall not enter into any settlement agreement or release with San Antonio with respect to the Lawsuit or the subject matter thereof without Buyer’s consent, which consent shall not be unreasonably withheld.

(d)    If Buyer in good faith believes the terms of the proposed Lawsuit Settlement of San Antonio with Prejudice would differ materially from those provided by Buyer to Seller in connection with this Section 2.3, then it shall so notify Seller, the Parties shall confer and discuss such material deviations prior entering into any Lawsuit Settlement of San Antonio with Prejudice, but no Party shall have any obligation to make any changes in the agreements set forth herein.

(e)    If Buyer enters into any settlement agreement or release with Austin with respect to the Lawsuit or the subject matter thereof, such settlement agreement or release shall release Seller and its Affiliates from all claims of Austin in the Lawsuit to the same extent Buyer and its Affiliates are released.

5.Addition of Section 6.21. A new Section 6.21 of the Purchase Agreement is hereby added as follows:

“Section 6.21    Dry Cask Amounts. To the extent that, after the Closing, Buyer or any of its Affiliates (including Constellation South Texas) receives any payment from the Qualified Decommissioning Fund in respect of dry cask expenditures that were submitted for reimbursement from the Qualified Decommissioning Fund prior to Closing but were not reimbursed prior to Closing, Buyer shall remit to Seller an amount equal to the payment received from the Qualified Decommissioning Fund for such reimbursement promptly after receipt thereof; provided, however, that in no event shall Buyer remit to Seller pursuant to this Section 6.21 any such amounts in the aggregate in excess of $150,000.”

6.References to and Effect on the Purchase Agreement. Except as expressly amended by this Amendment, all of the terms, conditions, and other provisions of the Purchase Agreement shall continue to be in force and effect in accordance with their respective terms. No reference to this Amendment need be made in any instrument or document making reference to the Purchase Agreement, and any reference to the Purchase Agreement in any such instrument or document shall be deemed to refer to the Purchase Agreement as amended by this Amendment.

7.Miscellaneous. Article XIII (Miscellaneous) of the Purchase Agreement shall apply to this Amendment to the same extent as if set forth herein, mutatis mutandis.

(signatures follow)

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Execution Version

IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be duly executed on the day and year first above written.

CONSTELLATION ENERGY GENERATION, LLC

By:

Name: Bryan C. Hanson

Title: EVP & Chief Generation Officer

TEXAS GENCO GP, LLC

By:

Name: Dudley D. Zahn

Title: Vice President

TEXAS GENCO LP, LLC

By:

Name: Dudley D. Zahn

Title: Vice President

EX-10.10

Exhibit 10.10

NRG Energy, Inc. Amended and Restated Executive Change-in-Control
and General Severance Plan for Tier IA and Tier IIA Executives

Amended and Restated, effective January 1, 2024

LEGAL\66819657\5 1611203/00493825

TABLE OF CONTENTS

Page

Article 1.Establishment and Term of the Plan................................. 1

Article 2.Definitions........................................................................ 2

Article 3.Severance Benefits........................................................... 6

Article 4.Ineligibility..................................................................... 10

Article 5.Restrictive Covenants..................................................... 11

Article 6.Certain Change in Control Payments............................. 16

Article 7.Legal Fees and Notice.................................................... 17

Article 8.Successors and Assignment............................................ 17

Article 9.Miscellaneous................................................................. 17

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NRG Energy, Inc.
Amended and Restated Executive Change-in-Control
and General Severance Plan for Tier I and Tier II Executives

Article 1.Establishment and Term of the Plan

1.1Establishment of the Plan. NRG Energy, Inc. (hereinafter referred to as the “Company”) hereby adopts this plan known as the “NRG Energy, Inc. Amended and Restated Executive Change-in-Control and General Severance Plan for Tier I and Tier II Executives” (the “Plan”). This Plan was amended and restated as of August 1, 2016, and was further amended as of April 1, 2018 and January 1, 2024. The Plan provides Severance Benefits to Tier IA Executives and Tier IIA Executives of the Company (each an “Executive” and collectively the “Executives”) upon certain terminations of employment from the Company.

The Company considers the establishment and maintenance of a sound and vital management to be essential to protecting and enhancing the best interests of the Company and its stockholders. In this connection, the Company recognizes that, as is the case with many publicly held corporations, the possibility of a Change in Control may arise and that such possibility, and the uncertainty and questions which it may raise among management, may result in the departure or distraction of management personnel to the detriment of the Company and its stockholders.

Accordingly, the Board has determined that appropriate steps should be taken to reinforce and encourage the continued attention and dedication of members of the Company’s management to their assigned duties without distraction in circumstances arising from the possibility of a Change in Control of the Company.

1.2Initial Term. This Plan commenced on July 23, 2009 (the “Effective Date”) and continued for a period of three (3) years (the “Initial Term”).

1.3Successive Periods. The term of this Plan was automatically extended for one (1) additional year at the end of the Initial Term, and then again after each successive one (1) year period thereafter (each such one (1) year period following the Initial Term is referred to as a “Successive Period”). The Committee may, however, terminate this Plan at the end of any Successive Period by giving the Executives written notice of intent to terminate the Plan, delivered at least six (6) months prior to the end of such Successive Period. If such notice is properly delivered by the Company, this Plan, along with all corresponding rights, duties, and covenants, shall automatically expire at the end of the Successive Period then in progress.

1.4Change-in-Control Renewal. Notwithstanding the provisions of Section 1.3 above, in the event that a Change in Control of the Company occurs during any Successive Period, upon the effective date of such Change in Control, the term of this Plan shall automatically and irrevocably be renewed for a period of two (2) years from the effective date of such Change in Control. Further, this Plan may be assigned to the successor in such Change in Control, as further provided in Article 8 herein. This Plan shall thereafter automatically terminate following such two (2) year Change-in-Control renewal period; provided that such termination shall not affect or diminish the rights of Executives who become entitled to benefits or payments under this Plan.

Article 2.Definitions

Whenever used in this Plan, the following terms shall have the meanings set forth below and, when the meaning is intended, the initial letter of the word is capitalized.

(a)“Accountants” shall have the meaning set forth in Article 6.

(b)“Base Salary” means the greater of the Executive’s annual rate of salary, whether or not deferred, at: (i) the Effective Date of Termination or (ii) at the date of the Change in Control.

(c)“Beneficiary” means the persons or entities designated or deemed designated by the Executive pursuant to Section 9.6 herein.

(d)“Board” means the Board of Directors of the Company.

(e)“Cause”shall mean one or more of the following:

(i)the Executive’s willful misconduct or gross negligence in the performance of the Executive’s duties to the Company that has or could reasonably be expected to have an adverse effect on the Company;

(ii)the Executive’s willful failure to perform the Executive’s duties to the Company (other than as a result of death or a physical or mental incapacity);

(iii)indictment for, conviction of, or pleading of guilty or nolo contendere to, a felony or any crime involving moral turpitude;

(iv)the Executive’s performance of any material act of theft, fraud, malfeasance or dishonesty in connection with the performance of the Executive’s duties to the Company;

(v)breach of any written agreement between the Executive and the Company, or a violation of the Company’s code of conduct or other written policy; or

(vi)any other material breach of Article 5 of this Plan.

For purposes of this Plan, there shall be no termination for Cause pursuant to subsections (i) through (vi) above, unless a written notice, containing a detailed description of the grounds constituting Cause hereunder, is delivered to the Executive stating the basis for the termination. Upon receipt of such notice, the Executive shall be given thirty (30) days to fully cure and remedy the neglect or conduct that is the basis of such claim, provided that the Executive’s right to cure shall not apply if there are egregious, habitual or repeated breaches by the Executive.

(f)“Change-in-Control Severance Benefits” means the Severance Benefit described in Section 3.2.

(g)“Change in Control” shall mean the first to occur of any of the following events:

(i)Any “person” (as that term is used in Sections 13 and 14(d)(2) of the Securities Exchange Act of 1934 (“Exchange Act”)) becomes the “Beneficial Owner” (as that term is used in Section 13(d) of the Exchange Act), directly or indirectly, of fifty percent (50%) or more of the Company’s capital stock entitled to vote in the election of directors, excluding any “person” who becomes a “beneficial owner” in connection with a Business Combination (as defined in paragraph (iii) below) which does not constitute a Change in Control under said paragraph (iii); or

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(ii)Persons who on the Effective Date constitute the Board (the “Incumbent Directors”) cease for any reason, including without limitation, as a result of a tender offer, proxy contest, merger, or similar transaction, to constitute at least a majority thereof, provided that any person becoming a director of the Company subsequent to the Effective Date shall be considered an Incumbent Director if such person’s election or nomination for election was approved by a vote of at least two-thirds (2/3) of the Incumbent Directors; but provided further, that any such person whose initial assumption of office is in connection with an actual or threatened election contest relating to the election of members of the Board or other actual or threatened solicitation of proxies or consents by or on behalf of a “person” (as defined in Sections 13(d) and 14(d) of the Exchange Act) other than the Board, including by reason of agreement intended to avoid or settle any such actual or threatened contest or solicitation, shall not be considered an Incumbent Director; or

(iii)Consummation of a reorganization, merger, consolidation, or sale or other disposition of all or substantially all of the assets of the Company (a “Business Combination”), in each case, unless, following such Business Combination, all or substantially all of the individuals and entities who were the beneficial owners of outstanding voting securities of the Company immediately prior to such Business Combination beneficially own, directly or indirectly, more than fifty percent (50%) of the combined voting power of the then outstanding voting securities entitled to vote generally in the election of directors, as the case may be, of the company resulting from such Business Combination (including, without limitation, a company which, as a result of such transaction, owns the Company or all or substantially all of the Company’s assets either directly or through one or more subsidiaries) in substantially the same proportions as their ownership, immediately prior to such Business Combination, of the outstanding voting securities of the Company; or

(iv)The stockholders of the Company approve any plan or proposal for the liquidation or dissolution of the Company.

(h)“Code” means the Internal Revenue Code of 1986, as amended, as amended, and the treasury regulations and other official guidance promulgated thereunder.

(i)“Committee” means the Compensation Committee of the Board or any other committee appointed by the Board to perform the functions of the Compensation Committee.

(j)“Company” means NRG Energy, Inc., a Delaware corporation, or any successor thereto as provided in Article 8 herein.

(k)“Confidential Information” shall have the meaning set forth in Section 5(a).

(l)“Delay Period” shall have the meaning set forth in Section 3.4(b).

(m)“Disability” shall mean a disability that would entitle Executive to payment of monthly disability payments under any Company long-term disability plan.

(n)“Effective Date” means the commencement date of this Plan as specified in Section 1.2 of this Plan.

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(o)“Effective Date of Termination” means the date on which a Qualifying Termination occurs, as defined hereunder, which triggers the payment of Severance Benefits hereunder.

(p)“Executive” shall have the meaning set forth in Section 1.1.

(q)“Former Parent Company” means Xcel Energy, Inc., a Minnesota corporation, or any successor thereto.

(r)“General Severance Benefits” means the Severance Benefit described in Section 3.3.

(s)“Good Reason” shall mean without the Executive’s express written consent the occurrence of any one or more of the following:

(i)The Company materially reduces the amount of the Executive’s then current Base Salary or the target for Executive’s annual bonus; or

(ii)A material reduction in the Executive’s benefits under or relative level of participation in the Company’s employee benefit or retirement plans, policies, practices, or arrangements in which the Executive participates as of the Effective Date of this Plan; or

(iii)A material diminution in the Executive’s title, authority, duties, or responsibilities or the assignment of duties to the Executive which are materially inconsistent with Executive’s position; or

(iv)The failure of the Company to obtain in writing the obligation to perform or be bound by the terms of this Plan by any successor to the Company or a purchaser of all or substantially all of the assets of the Company within fifteen (15) days after a merger, consolidation, sale, or similar transaction.

For purposes of this Plan, the Executive is not entitled to assert that Executive’s termination is for Good Reason unless the Executive gives the Board written notice of the event or events which are the basis for such claim within ninety (90) days after the event or events occur, describing such claim in reasonably sufficient detail to allow the Board to address the event or events and a period of not less than thirty (30) days after to cure or fully remedy the alleged condition.

(t)“Initial Term”shall have the meaning set forth in Section 1.2.

(u)“Restricted Period”shall have the meaning set forth in Section 5(c).

(v)“Notice of Termination” shall mean a written notice which shall indicate the specific termination provision in this Plan relied upon, and shall set forth in reasonable detail the facts and circumstances claimed to provide a basis for termination of the Executive’s employment under the provision so indicated.

(w)“Original Plan” shall mean the NRG Energy, Inc. Amended and Restated Executive Change-in-Control and General Severance Plan, amended and restated effective December 9, 2008.

(x)“Parachute Payment Ratio” shall have the meaning set forth in Article 6.

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(y)“Plan” shall have the meaning set forth in Section 1.1.

(z)“Qualifying Termination” means:

(i)If such event occurs within the time period that is six (6) months immediately prior to, or twenty-four (24) months immediately following a Change in Control:

(A)An involuntary termination of the Executive’s employment by the Company for reasons other than Cause, death, or Disability pursuant to a Notice of Termination delivered to the Executive by the Company; or

(B)A voluntary termination by the Executive for Good Reason pursuant to a Notice of Termination delivered to the Company by the Executive; or

(ii)If such event occurs at any other time:

(A)An involuntary termination of the Executive’s employment by the Company for reasons other than Cause, death, or Disability pursuant to a Notice of Termination delivered to the Executive by the Company.

(aa)“Release Effective Date” shall have the meaning set forth in Section 3.1(d).

(ab)“Severance Benefits” means the payment of Change-in-Control or General (as

appropriate) Severance compensation as provided in Article 3 herein.

(ac)“Specified Employee” means any Executive described in Section 409A(a)(2)(B)(i) of the Code.

(ad)“Successive Period” shall have the meaning set forth in Section 1.3.

(ae)“Third Party Information” shall have the meaning set forth in Section 5(a).

(af)“Tier IA Executives” shall include those employees of the Company with the Job Level of EVP prior to the Change in Control, or such other employee who is designated as a Tier IA Executive in the Company’s human resources information system immediately prior to the Change in Control other than the CEO.

(ag)“Tier IIA Executives” shall include those employees of the Company with the Job Level of SVP prior to the Change in Control, or such other employee who is designated as a Tier IIA Executive in the Company’s human resources information system immediately prior to the Change in Control.

(ah)“Total Payments” shall have the meaning set forth in Article 6.

(ai)“Work Product” shall have the meaning set forth in Section 5(b).

Article 3.Severance Benefits

1.1Right to Severance Benefits

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(a)Change-in-Control Severance Benefits. The Executive shall be entitled to receive from the Company Change-in-Control Severance Benefits, as described in Section 3.2 herein, if a Qualifying Termination of the Executive’s employment has occurred within six (6) months immediately prior to, or twenty-four (24) months immediately following, a Change in Control of the Company.

(b)General Severance Benefits. The Executive shall be entitled to receive from the Company General Severance Benefits, as described in Section 3.3 herein, if a Qualifying Termination of the Executive’s employment has occurred other than during the six (6) months immediately prior to, or twenty-four (24) months immediately following, a Change in Control.

(c)No Severance Benefits. The Executive shall not be entitled to receive Severance Benefits if the Executive’s employment with the Company ends for reasons other than a Qualifying Termination.

(d)General Release and Acknowledgement of Restrictive Covenants. As a condition to receiving Severance Benefits under either Section 3.2 or 3.3 herein, the Executive shall be obligated to execute a severance agreement and general release of claims in favor of the Company, its current and former affiliates and stockholders, and the current and former directors, officers, employees, and agents of the Company in a form drafted by and acceptable to the Company, and any revocation period for such severance agreement and general release must have expired, in each case within sixty (60) days of the date of termination. The date upon which the executed severance agreement and general release is no longer subject to revocation shall be referred to herein as the “Release Effective Date.” The Executive must also execute a notice acknowledging the restrictive covenants in Article 5 within sixty (60) days of the date of termination. Notwithstanding the foregoing, the Administrator shall have discretion to reasonably enlarge (but not reduce) the time period for the Executive to consider the severance agreement and general release, and to acknowledge the restrictive covenants, if the Administrator determines that such enlargement is necessary for the Executive to effectively review the severance agreement and general release or to secure the advice and input of counsel. Any payments under Section 3.2 or 3.3 shall commence only after execution of the severance agreement and general release and the acknowledgement, and in the manner provided in Section 3.4. Notwithstanding the foregoing, in any instance in which the period in which the Executive could accept the severance agreement and general release (along with its accompanying revocation period) crosses calendar years, no payments shall be made until the succeeding calendar year.

(e)No Duplication of Severance Benefits. If the Executive becomes entitled to Change-in-Control Severance Benefits, the Severance Benefits provided for under Section 3.2 hereunder shall be in lieu of all other Severance Benefits provided to the Executive under the provisions of this Plan and any other Company-related or Former Parent Company-related severance plans, programs, or agreements including, but not limited to, the Severance Benefits under Section 3.3 herein. Likewise, if the Executive becomes entitled to General Severance Benefits, the Severance Benefits provided under Section 3.3 hereunder shall be in lieu of all other Severance Benefits provided to the Executive under the provisions of this Plan and any other Company-related severance plans, programs, or other agreements including, but not limited to, the Severance Benefits under Section 3.2 herein.

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1.2Description of Change-in-Control Severance Benefits. In the event the Executive becomes entitled to receive Change-in-Control Severance Benefits, as provided in Section 3.1(a) herein, the Company shall provide the Executive with the following:

(a)A lump-sum amount, paid upon the date that is sixty (60) calendar days following the Effective Date of Termination, equal to the Executive’s unpaid Base Salary, accrued vacation pay, unreimbursed business expenses, and all other items earned by and owed to the Executive through and including the Effective Date of Termination, provided that to the extent the payment of any amounts pursuant to this Section 3.2(a) does not constitute “deferred compensation” for purposes of Code Section 409A, such amounts shall be paid upon the Release Effective Date. Notwithstanding the foregoing, in any instance in which the period in which the Executive could accept the severance agreement and general release (along with its accompanying revocation period) crosses calendar years, no payments shall be made until the succeeding calendar year.

(b)A lump-sum amount, paid upon the date that is sixty (60) calendar days following the Effective Date of Termination, equal to: (i) two and ninety-nine one-hundredths (2.99) for Tier I Executives, or (ii) two (2) for Tier II Executives times the sum of the following: (A) the Executive’s Base Salary and (B) the Executive’s annual target bonus opportunity in the year of termination; provided that to the extent the payment of any amounts pursuant to this Section 3.2(b) does not constitute “deferred compensation” for purposes of Code Section 409A, such amounts shall be paid upon the Release Effective Date. Notwithstanding the foregoing, in any instance in which the period in which the Executive could accept the severance agreement and general release (along with its accompanying revocation period) crosses calendar years, no payments shall be made until the succeeding calendar year.

(c)A lump-sum amount, paid upon the date that is sixty (60) calendar days following the Effective Date of Termination, equal to the Executive’s then current target bonus opportunity established under the bonus plan in which the Executive is then participating, for the plan year in which a Qualifying Termination occurs, adjusted on a pro rata basis based on the number of days the Executive was actually employed during the bonus plan year in which the Qualifying Termination occurs, provided that to the extent the payment of any amounts pursuant to this Section 3.2(c) does not constitute “deferred compensation” for purposes of Code Section 409A, such amounts shall be paid upon the Release Effective Date. Notwithstanding the foregoing, in any instance in which the period in which the Executive could accept the severance agreement and general release (along with its accompanying revocation period) crosses calendar years, no payments shall be made until the succeeding calendar year.

(d)Payment of all or a portion of the Executive’s cost to participate in COBRA medical and dental continuation coverage for eighteen (18) months following the Executive’s Effective Date of Termination, such that Executive maintains the same coverage level and cost, on an after tax basis, as in effect immediately prior to the Executive’s Effective Date of Termination.

Notwithstanding the above, these medical benefits shall be discontinued prior to the end of the stated continuation period in the event the Executive is eligible to receive substantially similar benefits from a subsequent employer, as determined solely by the Committee in good faith. For purposes of enforcing this offset provision, the Executive shall be deemed to have a duty to keep the Company

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informed as to the terms and conditions of any subsequent employment and the corresponding benefits earned from such employment, and shall provide, or cause to provide, to the Company in writing correct, complete, and timely information concerning the same.

(e)Treatment of outstanding long-term incentives shall be in accordance with the governing plan document and award agreements, if any.

1.3Description of General Severance Benefits. In the event the Executive becomes entitled to receive General Severance Benefits as provided in Section 3.1(b) herein, the Company shall provide the Executive with the following:

(a)A lump-sum amount, paid upon the date that is sixty (60) calendar days following the Effective Date of Termination, equal to the Executive’s unpaid Base Salary, accrued vacation pay, unreimbursed business expenses, and all other items earned by and owed to the Executive through and including the Effective Date of Termination; provided that to the extent the payment of any amounts pursuant to this Section 3.3(a) does not constitute “deferred compensation” for purposes of Code Section 409A, such amounts shall be paid upon the Release Effective Date. Notwithstanding the foregoing, in any instance in which the period in which the Executive could accept the severance agreement and general release (along with its accompanying revocation period) crosses calendar years, no payments shall be made until the succeeding calendar year.

(b)A lump-sum amount, paid upon the date that is sixty (60) calendar days following the Effective Date of Termination, equal to one and one-half (1.5) times the Executive’s Base Salary; provided that to the extent the payment of any amounts pursuant to this Section 3.3(b) does not constitute “deferred compensation” for purposes of Code Section 409A, such amounts shall be paid upon the Release Effective Date. Notwithstanding the foregoing, in any instance in which the period in which the Executive could accept the severance agreement and general release (along with its accompanying revocation period) crosses calendar years, no payments shall be made until the succeeding calendar year.

(c)Payment of all or a portion of the Executive’s cost to participate in COBRA medical and dental continuation coverage for eighteen (18) months following the Executive’s Effective Date of Termination, such that Executive maintains the same coverage level and cost, on an after tax basis, as in effect immediately prior to the Executive’s Effective Date of Termination.

Notwithstanding the above, these medical insurance benefits shall be discontinued prior to the end of the stated continuation period in the event the Executive is eligible to receive substantially similar benefits from a subsequent employer, as determined solely by the Committee in good faith. For purposes of enforcing this offset provision, the Executive shall be deemed to have a duty to keep the Company informed as to the terms and conditions of any subsequent employment and the corresponding benefits earned from such employment, and shall provide, or cause to provide, to the Company in writing correct, complete, and timely information concerning the same.

(d)Treatment of outstanding long-term incentives shall be in accordance with the governing plan document and award agreements, if any.

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1.4Coordination with General Release and Delay Required by Code Section 409A.

(a)To the extent any continuing benefit (or reimbursement thereof) to be provided is not “deferred compensation” for purposes of Code Section 409A, then such benefit shall commence or be made immediately after the Release Effective Date. To the extent any continuing benefit (or reimbursement thereof) to be provided is “deferred compensation” for purposes of Code Section 409A, then such benefits shall be reimbursed or commence upon the sixtieth (60) day following the Executive’s termination of employment. The delayed benefits shall in any event expire at the time such benefits would have expired had the benefits commenced immediately upon Executive’s termination of employment.

(b)Notwithstanding any other payment schedule provided herein to the contrary, if the Executive is deemed on the date of termination to be a Specified Employee, then, once the severance agreement and general release and the acknowledgement required by Section 3.1(d)areexecuted and delivered and no longer subject to revocation, any payment that is considered deferred compensation under Code Section 409A payable on account of a “separation from service” shall be made on the date which is the earlier of (A) the expiration of the six (6)-month period measured from the date of such “separation from service” of the Executive, and (B) the date of the Executive’s death (the “Delay Period”) to the extent required under Code Section 409A. Upon the expiration of the Delay Period, all payments delayed pursuant to this Section 3.4(b) (whether they would have otherwise been payable in a single sum or in installments in the absence of such delay) shall be paid to the Executive in a lump sum, and any remaining payments due under this Plan shall be paid or provided in accordance with the normal payment dates specified for them herein.

Article 4.Ineligibility

1.1Comparable Position.

Subject to the provisions of Section 2(z)(i)(B), the Company may offer an Executive a comparable position, may require an Executive to apply for a comparable position with the Company or any affiliate, or may reassign an Executive to a new position or a reclassification of the Executive’s current position; provided, that all such positions shall be located within reasonably the same geographic area where the Executive is located at the time a Qualifying Termination occurs. The Company shall determine, in its sole and reasonable discretion, what constitutes a comparable position under this Section 4.1. The failure of an Executive to accept the position, or apply for the position when required by the Company will render the Executive ineligible for benefits under this Plan.

1.2Other Circumstances.

Unless otherwise determined by the Committee, an Executive shall also be ineligible for benefits under this Plan if the Executive:

(a)voluntarily terminates employment or retires prior to the Qualifying Termination;

(b)is receiving long-term Disability benefits;

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(c)is entitled to any other compensation or benefit which is determined, in the Company’s sole discretion, to supersede the Severance Benefits offered underthis Plan;

(d)was discharged for Cause; or

(e)was offered employment by a successor employer or by a purchaser in the event of a spin-off or sale of a subsidiary, business unit or business assets of the Company or its subsidiaries, whether or not the Executive accepts or declines the offer of employment, unless the Company has agreed in the applicable sale document or otherwise that such offer will not be disqualifying.

Article 5.Restrictive Covenants

In the event the Executive becomes entitled to receive Change-in-Control Severance Benefits as provided in Section 3.2 herein or General Severance Benefits as provided in Section 3.3 herein, the following shall apply, all subject to Executive’s Protected Rights (defined below):

(a)Confidential Information. The Executive acknowledges that the information, observations, and data (including trade secrets) obtained by Executive while employed by the Company concerning the business or affairs of the Company or any of its affiliates (“Confidential Information”) are the property of the Company or such affiliate. Therefore, except in the course of the Executive’s duties to the Company or as may be compelled by law or appropriate legal process, the Executive agrees that Executive shall not disclose to any person or entity or use for Executive’s own purposes any Confidential Information or any confidential or proprietary information of other persons or entities in the possession of the Company and its affiliates (“Third Party Information”), without the prior written consent of the Board, unless and to the extent that the Confidential Information or Third Party Information becomes generally known to and available for use by the public other than as a result of the Executive’s acts or omissions. Except in the course of the Executive’s duties to the Company or with respect to Protected Rights, the Executive will not, during Executive’s employment with the Company, or permanently thereafter, directly or indirectly use, divulge, disseminate, disclose, lecture upon, or publish any Confidential Information, without having first obtained written permission from the Board to do so.

As of the Effective Date of Termination, the Executive shall deliver to the Company, or at any other time the Company may reasonably request, all memoranda, notes, plans, records, reports, computer files, disks and tapes, printouts and software and other documents and data (and copies thereof), in any form, format or medium, whether hard-copy, digital, electronic or otherwise, embodying or relating to Third Party Information, Confidential Information, or the business of the Company, or its affiliates which Executive may then possess or have under Executive’s control. To the extent an electronic copy exists of the returned materials, Executive must permanently delete such electronic copy/copies on or before Executive’s Termination Date (following transmittal to the Company of such documents as set forth above). Executive understands that if Executive does not return any hardcopy paper documents and/or electronic media within the time period set forth above, Executive is affirming and representing to the best of Executive’s knowledge that Executive has no such materials in Executive’s possession or control.

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Nothing in this Plan will be interpreted to prohibit Executive from making truthful statements when compelled to provide information by a subpoena, court order, or other valid legal obligation. To the extent permitted by law, Executive will notify the Company immediately upon receiving notice of a subpoena, court order or other legal obligation that may require disclosure of Third Party Information or Confidential Information, so that the Company may take lawful steps to protect against any unnecessary, overbroad or unlawful disclosure or use of Third Party Information or Confidential Information.

Nothing in this Plan shall limit or restrict in any way Executive’s immunity from liability for disclosing the Company’s trade secrets as specifically permitted by 18 U.S. Code Section 1833, which provides, in pertinent part, as follows:

“(b) Immunity From Liability For Confidential Disclosure Of A Trade Secret To The Government Or In A Court Filing.

(1) Immunity. An individual shall not be held criminally or civilly liable under any Federal or State trade secret law for the disclosure of a trade secret that (A) is made (i) in confidence to a Federal, State, or local government official, either directly or indirectly, or to an attorney; and (ii) solely for the purpose of reporting or investigating a suspected violation of law; or (B) is made in a complaint or other document filed in a lawsuit or other proceeding, if such filing is made under seal.

(2) Use of Trade Secret Information in Anti-Retaliation Lawsuit. An individual who files a lawsuit for retaliation by an employer for reporting a suspected violation of law may disclose the trade secret to the attorney of the individual and use the trade secret information in the court proceeding, if the individual (A) files any document containing the trade secret under seal; and (B) does not disclose the trade secret, except pursuant to court order.”

(b)Intellectual Property, Inventions, and Patents. The Executive acknowledges that all discoveries, concepts, ideas, inventions, innovations, improvements, developments, methods, trade secrets, designs, analyses, drawings, reports, patent applications, copyrightable work and mask work (whether or not including any Confidential Information), and all registrations or applications related thereto, all other proprietary information and all similar or related information (whether or not patentable) which may relate to the Company’s or any of its affiliates’ actual or anticipated business, research and development, or existing or future products or services and which are conceived, developed, or made by the Executive (whether alone or jointly with others) while employed by the Company and its affiliates (“Work Product”), belong to the Company or such affiliate. The Executive shall promptly disclose such Work Product to the Board and, at the Company’s expense, perform all actions reasonably requested by the Board (whether during or after the Executive’s employment with the Company) to establish and confirm such ownership (including, without limitation, assignments, consents, powers of attorney, and other instruments). The Executive acknowledges that all applicable Work Product shall be deemed to constitute “works made for hire” under the U.S. Copyright Act of 1976, as amended. To the extent any Work Product is not deemed a work made for hire, then the Executive hereby assigns to the Company or such affiliate all right, title, and interest in and to such Work Product, including all related intellectual property rights.

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The Executive is hereby advised that the above paragraph regarding the Company’s and its affiliates’ ownership of Work Product does not apply to any invention for which no equipment, supplies, facilities, or trade secret information of the Company or any affiliate was used and which was developed entirely on the Executive’s own time, unless: (i) the invention relates to the business of the Company or any affiliate or to the Company’s or any affiliate’s actual or demonstrably anticipated research or development, or (ii) the invention results from any work performed by the Executive for the Company or any affiliate.

(c)Noncompete. In further consideration of the compensation to be paid to the Executive hereunder, the Executive acknowledges that during the course of Executive’s employment with the Company and its affiliates Executive shall become familiar with the Company’s trade secrets and with other Confidential Information concerning the Company and its affiliates and that Executive’s services shall be of special, unique, and extraordinary value to the Company and its affiliates, and therefore, the Executive agrees that, during the Executive’s employment with the Company and for one (1) year thereafter (the “Restricted Period”), without the prior written approval of an officer of the Company, Executive will not, whether as an employee, consultant, owner, employer, agent, principal, partner, corporate officer, director or in any other individual or representative capacity, directly or indirectly, engage in or make plans to engage in any employment and/or business activity that provides wholesale or retail power generation, smart home products and/or services, or any other business which competes with the businesses of the Company or its affiliates, as such businesses exist or are in process during the Executive’s employment with the Company (“Competing Business”) to any client or Prospective Client (as defined below) of the Company with whom Executive had Material Contact (as defined below) within 24 months prior to the end of Executive’s employment with the Company. “Prospective Client” means any person or entity for which the Company has sought, through personalized communication with such person or entity, to provide products or services at any time during the prior 24 months. “Material Contact” encompasses a client or Prospective Client of the Company with whom or which Executive dealt as a representative of the Company, or for which Executive had access to and/or knowledge of confidential information of by virtue of Executive’s employment with the Company. Nothing herein shall prohibit the Executive from being a passive owner of not more than two percent (2%) of the outstanding stock of any class of a corporation which is publicly traded, so long as the Executive has no active participation in the business of such corporation. Notwithstanding the foregoing, the provisions of this Section 5(c) shall not apply in the case of termination of the Executive’s employment pursuant to any material breach of the Company’s obligations under Article 3 which remains uncured for more than twenty (20) days after notice is received from the Executive of such breach, which such notice shall include a detailed description of the grounds constituting such breach. Further, notwithstanding the foregoing, given American Bar Association Model Rule of Professional Conduct 5.6, and analogous state rules regulating the professional conduct of lawyers, the provisions of this Section 5(c) shall not apply solely with respect to the provision of legal services by Executive if Executive is a licensed attorney.

The non-competition obligations of this Section will not apply if Executive’s principal work location is in California, Minnesota, or any other jurisdiction where such provisions would not be enforced as a matter of clearly controlling law. If Executive is unsure whether the non-competition obligations of this Section apply to the Executive, the Executive should contact Human Resources.

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(d)Nonsolicitation. During the Restricted Period, the Executive shall not directly or indirectly through another person or entity: (i) induce or attempt to induce any employee of the Company or any of its affiliates to leave the employ of the Company or such affiliate, or in any way interfere with the relationship between the Company or any affiliate and any employee thereof; (ii) recruit and/or hire any employee of the Company or any affiliate (or any employee who has been employed by the Company or any affiliate at any time during the last six (6) months of the Executive’s employment with the Company) to work with or perform services for a Competing Business; or (iii) induce or attempt to induce any customer, supplier, licensee, licensor, franchisee, or other business relation of the Company or any affiliate to cease doing business with the Company or such affiliate, or in any interfere with the relationship between any such customer, supplier, licensee, or business relation and the Company or any affiliate (including, without limitation, making any negative or disparaging statements or communications regarding the Company or its affiliates).

The customer and employee non-solicitation obligations of this Section will not apply if Executive’s principal work location is in California or any other jurisdiction where such provisions would not be enforced as a matter of clearly controlling law. The customer non-solicitation obligations of this Section will not apply if Executive’s principal work location is in Nevada or Virginia and a customer seeks the services of Executive without any contact instigated by Executive. If Executive is unsure whether the customer and/or employee non-solicitation obligations of this Section apply to the Executive, the Executive should contact Human Resources.

(e)Comment to Others. Except as to Protected Rights, during the Restricted Period, Executive shall not disparage the Company, its subsidiaries and parents, and their respective officers, managers and employees, or make any public statement (whether written or oral) reflecting negatively on the Company, its subsidiaries and parents, and their respective officers, managers, and employees, including, but not limited to, any matters relating to the operation or management of the Company, irrespective of the truthfulness or falsity of such statement, except as may otherwise be required by applicable law or compelled by process of law. By way of example and not limitation, Executive agrees that Executive will not make any written or oral statements that cast in a negative light the services, qualifications, business operations or business ethics of the Company or its employees. Nothing in this Section 5(e) shall restrict either party’s ability to: (i) consult with counsel, (ii) make truthful statements under oath or to a government agency or official, or (iii) take any legal action with respect to Executive’s employment or termination of employment with the Company.

(f)Protected Rights. Executive shall retain the following “Protected Rights”: Nothing in this Plan prevents Executive from consulting with counsel; from complying with a valid court order; from reporting unlawful conduct to a law enforcement agency or testifying in a proceeding regarding alleged sexual harassment or otherwise unlawful conduct; from discussing or disclosing information about unlawful acts in the workplace or at work related events, such as harassment, discrimination, illegal retaliation, sexual harassment, sexual assault, wage and hour violations, or any other conduct that Executive has reason to believe is unlawful, an unfair employment practice, or against a clear mandate of public policy; from filing a charge or complaint with a Government Agency; from communicating with a Government Agency; or from otherwise participating in a Government Agency investigation or proceeding, including receiving an

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award paid by a Government Agency for providing information to a Government Agency. For purposes of this Plan, a “Government Agency” is defined as any federal, state or local governmental agency or commission, including but not limited to the U.S. National Labor Relations Board, the U.S. Occupational Safety and Health Administration, the U.S. Securities and Exchange Commission, the U.S. Equal Employment Opportunity Commission, and any similar state or local agencies.

(g)Duration, Scope, or Area. If, at the time of enforcement of this Article 5, a court shall hold that the duration, scope, or area restrictions stated herein are unreasonable under circumstances then existing, the parties agree that the maximum duration, scope, or area reasonable under such circumstances shall be substituted for the stated duration, scope, or area and that the court shall be allowed to revise the restrictions contained herein to cover the maximum period, scope, and area permitted by law.

(h)Company Enforcement. In the event of a breach or a threatened breach by the Executive of any of the provisions of this Article 5, the Company would suffer irreparable harm, and in addition and supplementary to other rights and remedies existing in its favor, the Companyshall be entitled to specific performance and/or injunctive or other equitable relief from a court of competent jurisdiction in order to enforce or prevent any violations of the provisions hereof (without posting a bond or other security). In addition, in the event of a breach or violation by the Executive of Section 5(c), the Restricted Period shall be automatically extended by the amount of time between the initial occurrence of the breach or violation and when such breach or violation has been duly cured.

(i)Consideration for Article 5 Covenants. The parties agree that Executive’s Participation in this Plan, with its opportunity for Change-in-Control Severance Benefits as provided in Section 3.2 herein or General Severance Benefits as provided in Section 3.3 herein, constitutes sufficient consideration for the covenants in Article 5 of the Plan.

Article 6.Certain Change in Control Payments

Notwithstanding any provision of the Plan to the contrary, if any payments or benefits an Executive would receive from the Company under the Plan or otherwise in connection with the Change in Control (the “Total Payments”) (a) constitute “parachute payments” within the meaning of Section 280G of the Code, and (b) but for thisArticle 6, would be subject to the excise tax imposed by Section 4999 of the Code, then such Executive will be entitled to receive either (i) the full amount of the Total Payments or (ii) a portion of the Total Payments having a value equal to One Dollar ($1) less than three (3) times such individual’s “base amount” (as such term is defined in Section 280G(b)(3)(A) of the Code), whichever of (i) and (ii), after taking into account applicable federal, state, and local income taxes and the excise tax imposed by Section 4999 of the Code, results in the receipt by such employee on an after-tax basis, of the greatest portion of the Total Payments. Any determination required under this Article 6 shall be made in writing by the Company’s independent certified public accountants appointed prior to any change in ownership (as defined under Section 280G(b)(2) of the Code) or tax counsel selected by such accountants (the “Accountants”), whose determination shall be conclusive and binding for all purposes upon the applicable Executive. For purposes of making the calculations required by this Article 6, the Accountants may make reasonable assumptions and approximations concerning applicable taxes and may rely on reasonable, good-faith interpretations concerning the application of Sections 280G and 4999 of the Code. If there is a reduction pursuant to this Article 6 of the Total Payments to be delivered to the applicable Executive, the payment

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reduction contemplated by the preceding sentence shall be implemented by determining the Parachute Payment Ratio (as defined below) for each “parachute payment” and then reducing the “parachute payments” in order beginning with the “parachute payment” with the highest Parachute Payment Ratio. For “parachute payments” with the same Parachute Payment Ratio, such “parachute payments” shall be reduced based on the time of payment of such “parachute payments,” with amounts having later payment dates being reduced first. For “parachute payments” with the same Parachute Payment Ratio and the same time of payment, such “parachute payments” shall be reduced on a pro rata basis (but not below zero) prior to reducing “parachute payments” with a lower Parachute Payment Ratio. For purposes hereof, the term “Parachute Payment Ratio” shall mean a fraction the numerator of which is the value of the applicable “parachute payment” for purposes of Section 280G of the Code and the denominator of which is the actual present value of such payment.

Article 7.Legal Fees and Notice

1.1Payment of Legal Fees. Except as otherwise agreed to by the parties, the Company and the Executive shall bear their own costs of litigation or other disputes including, without limitation, reasonable attorneys’ fees incurred by the Company or Executive in asserting any claims or defenses under this Plan; provided, however, that the Company shall reimburse Executive’s reasonable and necessary costs of such litigation or disputes (including, without limitation, attorneys’ fees) if the court (or arbitrator) finds in favor of the Executive with respect to any material claims or defenses asserted by the Executive.

1.2Notice. Any notices, requests, demands, or other communications provided for by this Plan shall be sufficient if in writing and if sent by registered or certified mail to the Executive at the last address they have filed in writing with the Company or, in the case of the Company, at its principal offices.

Article 8.Successors and Assignment

1.1Successors to the Company. The Company shall require any successor (whether direct or indirect, by purchase, merger, reorganization, consolidation, acquisition of property or stock, liquidation, or otherwise) of all or a significant portion of the assets of the Company by agreement, in form and substance satisfactory to the Executive, to expressly assume and agree to perform under this Plan in the same manner and to the same extent that the Company would be required to perform if no such succession had taken place. Regardless of whether such agreement is executed, the terms of this Plan shall be binding upon any successor in accordance with the operation of law and such successor shall be deemed the “Company” for purposes of this Plan.

1.2Assignment by the Executive. This Plan shall inure to the benefit of and be enforceable by the Executive’s personal or legal representatives, executors, administrators, successors, heirs, distributees, devisees, and legatees. If the Executive dies while any amount would still be payable to the Executive hereunder had they continued to live, all such amounts, unless otherwise provided herein, shall be paid in accordance with the terms of this Plan to the Executive’s Beneficiary. If the Executive has not named a Beneficiary, then such amounts shall be paid to the Executive in accordance with the Company’s regular payroll practices or to the Executive’s estate, as applicable.

Article 9.Miscellaneous

1.1Employment Status. Except as may be provided under any other agreement between the Executive and the Company, the employment of the Executive by the Company is

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“at will” and may be terminated by either the Executive or the Company at any time, subject to applicable law.

1.2Code Section 409A.

(a)All expenses or other reimbursements under this Plan shall be made on or prior to the last day of the taxable year following the taxable year in which such expenses were incurred by the Executive (provided that if any such reimbursements constitute taxable income to the Executive, such reimbursements shall be paid no later than March 15th of the calendar year following the calendar year in which the expenses to be reimbursed were incurred), and no such reimbursement or expenses eligible for reimbursement in any taxable year shall in any way affect the expenses eligible for reimbursement in any other taxable year.

(b)For purposes of Code Section 409A, the Executive’s right to receive any installment payment pursuant to this Plan shall be treated as a right to receive a series of separate and distinct payments.

(c)Whenever a payment under this Plan specifies a payment period with reference to a number of days (e.g., “payment shall be made within thirty (30) days following the date of termination”), the actual date of payment within the specified period shall be within the sole discretion of the Company.

(d)A termination of employment shall not be deemed to have occurred for purposes of any provision of this Plan providing for the payment of any amounts or benefits upon or following a termination of employment unless such termination is also a “separation from service” within the meaning of Code Section 409A and, for purposes of any such provision of this Plan, references to a “termination,” “termination of employment” or like terms shall mean “separation from service.”

(e)Notwithstanding any other provision of this Plan to the contrary, in no event shall any payment under this Plan that constitutes “deferred compensation” for purposes of Code Section 409A be subject to offset unless otherwise permitted by Code Section 409A.

(f)Notwithstanding any provisions in this Plan to the contrary, whenever a payment under this Plan may be made upon the Release Effective Date, and the period in which the Executive could accept the severance agreement and general release (along with its accompany revocation period) crosses calendar years, no payments shall be made until the succeeding calendar year.

1.3Entire Plan. This Plan supersedes any prior agreements or understandings, oral or written, between the parties hereto, with respect to the subject matter hereof, and constitutes the entire agreement of the parties with respect thereto. Without limiting the generality of the foregoing sentence, this Plan completely supersedes any and all prior employment agreements entered into by and between the Company and the Executive, and all amendments thereto, in their entirety. Notwithstanding the foregoing, if the Executive has entered into any agreements or commitments with the Company with regard to Confidential Information, noncompetition, nonsolicitation, or nondisparagement, such agreements or commitments will remain valid and will be read in harmony with this Plan to provide maximum protection to the Company. For the avoidance of doubt, the Original Plan shall remain outstanding, provided that following the Effective Date no additional employees shall become participants in the Original Plan and in no event shall any employee be entitled to participate in both this Plan and the Original Plan.

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1.4Severability. In the event that any provision or portion of this Plan shall be determined tobe invalid or unenforceable for any reason, the remaining provisions of this Plan shall beunaffected thereby and shall remain in full force and effect.

1.5Tax Withholding. The Company may withhold from any benefits payable under this Plan all federal, state, city, or other taxes as may be required pursuant to any law or governmental regulation or ruling.

1.6Beneficiaries. The Executive may designate one (1) or more persons or entities as the primary and/or contingent beneficiaries of any amounts to be received under this Plan.

Such designation must be in the form of a signed writing acceptable to the Board or the Board’s designee. The Executive may make or change such designation at any time.

1.7Payment Obligation Absolute. The Company’s obligation to make the payments provided for herein shall be absolute and unconditional (except for conditions set forth in the Plan), and shall not be affected by any circumstances, including, without limitation, any offset, counterclaim, recoupment, defense, or other right which the Company may have against the Executive or anyone else.

Except as provided in Article 3 of this Plan, the Executive shall not be obligated to seek other employment in mitigation of the amounts payable or arrangements made under any provision of this Plan, and the obtaining of any such other employment shall in no event effect any reduction of the Company’s obligations to make the payments and arrangements required to be made under this Plan.

1.8Contractual Rights to Benefits. Subject to approval and ratification by the Board, this Plan establishes and vests in the Executive a contractual right to the benefits to which the Executive is entitled hereunder. However, nothing herein contained shall require or be deemed to require, or prohibit or be deemed to prohibit, the Company to segregate, earmark, or otherwise set aside any funds or other assets, in trust or otherwise, to provide for any payments to be made or required hereunder.

1.9Modification. No provision of this Plan may be modified, waived, or discharged with respect to any particular Executive unless such modification, waiver, or discharge is agreed to in writing and signed by such Executive and by an authorized member of the Committee, or by the respective parties’ legal representatives and successors, provided, however, that the Committee may unilaterally amend this Plan without the Executive’s consent if such amendment does not materially adversely alter or impair in any significant manner any rights or obligations of the Executive under the Plan.

1.10Number. Except where otherwise indicated by the context, the plural shall include the singular and the singular shall include the plural.

1.11Applicable Law. To the extent not preempted by the laws of the United States, the laws of the state of Texas shall be the controlling law in all matters relating to this Plan.

IN WITNESS WHEREOF, NRG Energy; Inc. has caused this Plan document to be executed by a duly authorized officer effective as of January 1, 2024.

ATTEST

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NRG Energy, Inc.

Virginia Kinney
Senior Vice President, Head of Administration

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EX-10.23

Exhibit 10.23

NRG ENERGY, INC. LONG-TERM INCENTIVE PLAN NOTICE OF RELATIVE PERFORMANCE STOCK UNITS

%%FIRST_NAME_LAST_NAME%-%

%%ADDRESS_LINE_1%-%

%%ADDRESS_LINE_2%-%

%%CITY_STATE_ZIPCODE%-%

Congratulations on your selection as a Participant under the NRG Energy, Inc. Amended and Restated Long-Term Incentive Plan1 (“Plan”). This Notice of Relative Performance Stock Units (the “GrantNotice”) and the attached Relative Performance Stock Unit Agreement (collectively referred to as the “Agreement”) constitute an agreement between you and NRG Energy, Inc. (the “Company”) pursuant to Section 9 of the Plan. In the event of any inconsistency between the terms of this Agreement and the terms of the Plan, the Plan’s terms shall supersede and replace the conflicting terms of this Agreement. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan. You are sometimes referred to as the “Participant” in this Agreement.

%%FIRST_NAME_LAST_NAME%-% is hereby granted Relative Performance Stock Units

(“RPSUs”) as follows:

Date of Grant:	%%OPTION_DATE,’Month DD, YYYY’%-%
Performance Period:	January 2, 2024 through January 2, 2027
Target Award:	%%TOTAL_SHARES_GRANTED,’999,999,999’%-%
Final Award:	Target Award multiplied by “Payout Percentage” based on the Company’s total shareholder return relative to total shareholder return of peer group members of the Standard & Poors 500 Index, as set forth in this Agreement.

Payment of the Final Award shall be made in NRG Energy, Inc. Common Stock and shall be made no earlier than January 2, 2027 and no later than March 15, 2027, subject to the terms and conditions of the Agreement.

Subject to Section 8 of this Agreement, if your employment by, or service to, the Company is terminated at any time during the Performance Period, any award or right granted hereunder shall expire and be forfeited, and no Final Award or dividend equivalent related thereto shall be paid.

____________________ If you disagree with any of the terms of this award or choose not to accept this award, please contact Peter Johnson at 609-524-4759 within 45 days of the Date of Grant. Otherwise, you will be deemed to have accepted this award under the terms and conditions set forth in this Agreement and the Plan.

1 As amended and restated on April 27, 2017.

2024 RPSU Agreement (SVP_EVP)

NRG ENERGY, INC. LONG-TERM INCENTIVE PLAN RELATIVE PERFORMANCE STOCK UNIT AGREEMENT

This Relative Performance Stock Unit Agreement, dated as of the Date of Grant set forth in the Notice of Relative Performance Stock Units (the “Grant Notice,” and together with this Relative Performance Stock Unit Agreement, the “Agreement”) to which this Agreement is attached, is made between NRG Energy, Inc. (the “Company”) and the Participant, as set forth in the Grant Notice. The Grant Notice is included in, and made part of, this Agreement.

1. Performance Criteria and Award Determination

(a) General - Award Determination

Subject to the provisions of this Agreement and the provisions of the NRG Energy, Inc. Amended and Restated Long-Term Incentive Plan (the “Plan”), the Company hereby grants to the Participant the number of Relative Performance Stock Units (“RPSUs”), set forth in the Grant Notice (“Target Award”), each of which will have a value equivalent to one (1) share of the Company’s Common Stock.

At the end of the Performance Period, the Participant shall be entitled to receive a payment, payable in shares of the Company’s Common Stock, equal to the Target Award times a “Payout Percentage” (the “Final Award”); provided, that if the Fair Market Value of the payment due to the Participant in satisfaction of the Final Award is greater than the amount that is six (6) times the Fair Market Value of the Target Award, determined as of the Date of Grant (the “Cap”), the Payout Percentage shall be adjusted such that Fair Market Value of such payment does not exceed the Cap. The “Payout Percentage” is based on the achievement of the performance criteria set forth in Section 1(b) of this Agreement, as determined and certified in writing by the Compensation Committee of the Company’s Board of Directors (the “Committee”).

(b) Performance Criteria and Relative TSR Comparison

Except as provided in Section 8 of this Agreement, a “Payout Percentage” is used to determine the Final Award under this Agreement. Subject to Section 1(c) of this Agreement, the “Payout Percentage” shall be based upon the Company’s total shareholder return (“TSR”) percentile ranking, as determined pursuant to Section 2 of this Agreement, and the Company’s TSR percentile ranking relative to “Chart A” below.

Chart A
TSR Performance Relative to Companies in the Peer Group	Payout Percentage (% of Target)
75th Percentile or Above	200%
55th Percentile - TARGET	100%
25th Percentile	25%
Below the 25th Percentile	0%

(c) Relative TSR Comparison if absolute TSR of Company is less than negative 15%

Notwithstanding the foregoing, if the Company’s absolute TSR for the Performance Period is less

than negative fifteen percent (-15%), the Final Award will be based on the following chart.

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2024 RPSU Agreement (SVP_EVP)

Chart B
TSR Performance Relative to Companies in Peer Group	Payout (% of Target)
75th Percentile or Above	200%
65th Percentile - TARGET	100%
25th Percentile	25%
Below the 25th Percentile	0%

2. Measuring Performance and relative TSR Ranking

(a) Performance Measure and RPSUs

For purposes of determining the Final Award, as soon as practicable after the completion of the Performance Period, (i) the TSRs of the Company and the companies set forth on Exhibit A, which comprise the peer group for purposes of this Agreement (each company is referred to as a “PeerGroup Member”), shall be calculated pursuant to Section 2(d) and (ii) the relative ranking of the Company’s TSR for the Performance Period, as compared to the TSR for each Peer Group Member for the Performance Period, shall be determined and expressed as a percentile ranking as described in Section 2(b).

(b) Total Shareholder Percentile Ranking

The Company’s TSR percentile ranking is based on the TSR to the Company’s stockholders during the Performance Period, inclusive of dividends paid, relative to the TSR during the Performance Period, inclusive of dividends paid, achieved by each of the Peer Group Members.

The Company’s TSR percentile ranking shall be determined as follows: the TSR percentile ranking shall be determined by ranking the Company and each of the Peer Group Members from highest to lowest according to their respective TSRs. After this ranking, the percentile performance of the Company relative to the Peer Group Members will be determined as follows:

P=1 – R-1

N-1

where: “P” represents the percentile performance

“N” represents the number of Peer Group Members, including the Company, as of the

Vesting Date.

“R” represents the Company’s ranking among the Peer Group Members.

i.    In the event a bankruptcy proceeding is commenced during the Performance Period with respect to any Peer Group Member, or if at any time during the Performance Period a Peer Group Member is liquidated or delisted, such company shall be treated as having a TSR of negative one hundred (-100%) for the Performance Period for purposes of TSR percentile ranking.

ii.    In the event that a merger, acquisition or business combination of a Peer Group Member by or with another Peer Group Member is consummated during the Performance Period, then the entity that survives as a result of such merger, acquisition, or business

3

2024 RPSU Agreement (SVP_EVP)

combination will be considered a Peer Group Member for purposes of TSR percentile ranking for the Performance Period.

iii. In the event that a merger, acquisition or business combination of a Peer Group Member by or with an entity that is not a Peer Group Member is consummated during the Performance Period, and such Peer Group Member is the entity that survives as a result of such merger, acquisition, or business combination, then such Peer Group Member will continue to be considered a Peer Group Member for purposes of TSR percentile ranking for the Performance Period.

iv. In the event that (i) a Peer Group Member ceases to be a publicly-traded company, or (ii) a merger, acquisition or business combination of a Peer Group Member by or with an entity that is not Peer Group Member is consummated during the Performance Period, and such Peer Group Member is not the entity that survives as a result of such merger, acquisition, or business combination, then such Peer Group Member shall be removed and treated as if it had never been in the peer group for purposes of TSR percentile ranking for the Performance Period.

v.    In the event of a distribution of stock from a Peer Group Member (including the Company) consisting of shares of a new publicly traded company (a “spin-off”), the Peer Group Member shall remain a Peer Group Member and the stock distribution will be treated as a dividend from the Peer Group Member (including the Company) based on the closing price of the shares of the spin-off company on its first day of trading. The performance of the shares of the spin-off company shall not thereafter be treated for purposes of calculating TSR.

(c) Performance Period

The Performance Period, for purposes of this Agreement, shall be determined by the

Compensation Committee and shall be the period set forth in the Grant Notice.

(d) Performance Goal and TSR

For purposes of this Agreement, TSR for the Company and each of the Peer Group Members shall be measured by dividing (A) the difference between the average closing price of a share of such company’s common stock on the principal exchange on which such stock trades for the twenty (20) trading days occurring immediately prior to and including the first day of the Performance Period (the “Beginning Average Value”) including the impact of dividends that are reinvested on the ex-dividend date and the average closing price of a share of such stock on the principal exchange on which such stock trades for the twenty (20) trading days immediately prior to and including the last day of the Performance Period (the “Ending Average Value”) (appropriately adjusted for any stock dividend, stock split, spin-off, merger or other similar corporate events affecting such stock) including the impact of dividends that are reinvested on the ex-dividend date, by (B) the Beginning Average Value.

For the avoidance of doubt, it is intended that the foregoing calculation of TSR shall take into account not only the reinvestment of dividends in a share of common stock of the Company or any Peer Group Member, as applicable, but also capital appreciation or depreciation in the shares deemed acquired by such reinvestment. All determinations under this Section 2(d) shall be made by the Committee.

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2024 RPSU Agreement (SVP_EVP)

Illustration of formula described above

Total Shareholder Return = Ending Average Value – Beginning Average Value

Beginning Average Value

3. Settlement of Final Award

As soon as reasonably practicable following completion of all determinations and certifications contemplated by Sections 1 and 2, but in no event later than March 15 of the year following the year in which the Performance Period ends, subject to satisfaction of applicable tax withholding obligations in accordance with Section 12(g), the Company shall cause to be paid to the Participant the number of shares of the Company’s Common Stock equal to the product of the number of RPSUs representing the Final Award, as determined under Section 1 of this Agreement, multiplied by the Fair Market Value of a share of Common Stock as of the last trading day of the Performance Period, provided, however, that if the Participant incurs a Termination of Service that qualifies for payment of a Final Award as described in Section 8, then such payment shall be made on the next administratively feasible regularly scheduled payroll date but at no time more than sixty (60) days after the date a Final Award, if any, is determined or becomes payable, as described in the applicable subsection of Section 8, and, in accordance with Section 12(g), the Fair Market Value of the RPSUs shall be determined as of such date, less applicable taxes.

Notwithstanding the foregoing provisions of this Section 3 to the contrary, if at the time of the Participant’s separation from service within the meaning of Code Section 409A, the Participant is a “specified employee” within the meaning of Code Section 409A, any payment hereunder that constitutes a “deferral of compensation” under Code Section 409A and that would otherwise become due on account of such separation from service shall be delayed, and payment shall be made in full upon the earlier of (a) a date during the thirty (30) day period commencing six (6) months and one (1) day following such separation from service and (b) the date of the Participant’s death.

4. Dividend Equivalent Rights

Cash dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to the Target Award; provided that such cash dividends shall be deemed to be reinvested in shares of Common Stock immediately following the time declared at the then Fair Market Value of the Common Stock and shall be paid at the same time that the Final Award is delivered to the Participant in accordance with the provisions hereof. Stock dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to the Target Award; provided that such stock dividends shall be paid at the same time that the Final Award is delivered to the Participant in accordance with the provisions hereof. Notwithstanding the foregoing, in the event that there are insufficient shares of Common Stock available in the Plan to settle the accrued dividend book entry account in shares of Common Stock, such accrued book entry account shall be settled in cash in an amount equal to the Fair Market Value of such shares of Common Stock at the time of settlement. Except as otherwise provided herein, the Participant shall have no rights as a stockholder with respect to any shares of Common Stock underlying any RPSU unless and until the Participant has become the holder of record of such shares.

5. Transfer of RPSUs

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2024 RPSU Agreement (SVP_EVP)

Unless otherwise permitted by the Committee or Section 14 of the Plan, no award or right granted hereunder may be sold, transferred, pledged, assigned or otherwise alienated or hypothecated, other than pursuant to a will or the laws of descent and distribution. Any attempted disposition in violation of this Section 5 and Section 14 of the Plan shall be void.

6. Status of Participant

The Participant shall not be, and, except as otherwise provided herein, shall not have rights as, a stockholder of the Company with respect to any of the shares of Common Stock subject to, or underlying, the Target Award or Final Award, unless such shares have been issued and delivered to the Participant pursuant to the terms of this Agreement. The Company shall not be required to issue or transfer any certificates for shares of Common Stock until all applicable requirements of law have been complied with and such shares have been duly listed on any securities exchange on which the Common Stock may then be listed.

7. No Effect on Capital Structure

No award or right granted hereunder shall affect the right of the Company or any Subsidiary to reclassify, recapitalize or otherwise change its capital or debt structure or to merge, consolidate, convey any or all of its assets, dissolve, liquidate, windup, or otherwise reorganize.

8. Expiration and Forfeiture of Award

The Final Award, if any, shall be paid and/or expire in the circumstances described in this Section 8. As used herein, “Termination of Service” means termination of a Participant’s employment by, or service to, the Company, including any of its Subsidiaries.

(a) Death

Upon a Termination of Service by reason of death, a Final Award equal to one hundred percent (100%) of the Target Award shall be paid to the Participant’s legal representatives, heirs, legatees, or distributees in accordance with Section 3.

(b) Retirement

Upon a Termination of Service in the event of Retirement, the Award shall continue to vest according to the vesting schedule; provided that Retirement occurs more than twelve (12) months following the Date of Grant. Upon vesting, the Award shall be issued and delivered to the Participant in accordance with Sections 1 and 2, and any such Final Award shall be paid to the Participant in accordance with Section 3.

(c) Disability

Upon a Termination of Service as a result of Disability, a Final Award equal to one hundred percent

(100%) of the Target Award shall be paid to the Participant in accordance with Section 3.

(d) Change in Control

Notwithstanding any provision in this Section 8 to the contrary, if the Company terminates the Participant’s employment without Cause in connection with a Change in Control, the Final Award payable to the Participant, if any, shall be determined by the Committee and shall be paid to the Participant in accordance with Section 3. The Company’s termination of the Participant’s

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2024 RPSU Agreement (SVP_EVP)

employment may be treated as being in connection with a Change in Control only if such termination occurs during the period beginning six (6) months prior to the Change in Control and ending twenty-four (24) months following the Change in Control.

(e) Eligible Termination

Upon a Termination of Service by reason of an Eligible Termination (as defined below), the Participant shall continue to be eligible to receive a Final Award, if any, as though the Participant was continuously employed by the Company throughout the Performance Period. At the end of the Performance Period, the Company will determine the Final Award that the Participant would have received had the Participant been continuously employed by the Company throughout the Performance Period in accordance with Sections 1 and 2 (the “Performance Award”). The Performance Award shall then be pro-rated such that the total number of shares of Common Stock paid to the Participant shall be the percentage of the Performance Award that is equal to the percentage of time that the Participant was actually continuously employed by the Company during the Performance Period (the “Pro-rated Performance Award”). The Pro-rated Performance Award shall become payable to the Participant on the later to occur of (A) the date that the Final Award would have be delivered in accordance with Section 3 had the Participant been continuously employed by the Company throughout the Performance Period, and (B) on or about the fifteenth (15th) day of the month that follows the month in which the Release (as defined below) becomes irrevocable; provided, that (i) in the event the aggregate consideration and revocation period applicable to the Release spans two (2) calendar years, the applicable date under this Clause (B) will be on or about January 15 of the second calendar year and, (ii) in the event the aggregate consideration and revocation period applicable to the Release ends in December, the applicable date under this Clause (B) will be on or before the last day of that month of December. Upon becoming payable, the Pro-rated Performance Award shall be paid to the Participant in accordance with Section 3.

For purposes of this Section 8(e), “Eligible Termination” means an involuntary Termination of Service in connection with the sale of a business segment, restructuring or reduction in workforce. In order to be deemed an Eligible Termination, the Participant must execute and not revoke a general release of claims in favor of the Company in a form and with terms and conditions drafted by and acceptable to the Company, which is executed, and not revoked, by the Participant as a condition to receiving the benefit described herein (the “Release”). For the avoidance of doubt: (i) an involuntary Termination of Service by reason of a Change in Control, Cause, death, Disability, Good Reason, or not for Cause is not an Eligible Termination and (ii) in the event an Eligible Termination occurs and the Participant also meets the requirements for Retirement, the Award shall be paid in accordance with Section 8(b).

(f) Termination of Service other than as a result of Death, Retirement, Disability, Eligible Termination, or Change in Control

Upon a Termination of Service by any reason other than death, Retirement, Disability, Eligible Termination or without Cause in connection with a Change in Control, including, without limitation, as a result of retirement or disability that does not meet the requirements set forth in the definitions of such terms in the Plan, any award or right granted hereunder shall expire and be forfeited, and no Final Award or dividend equivalent related thereto shall be paid.

(g) Clawback as a result of misconduct

Unless otherwise determined by the Committee, if the Company is required to prepare a material restatement of its financial statements as a result of misconduct, and the Committee determines that the Participant knowingly engaged in the misconduct, was grossly negligent with respect to such misconduct, or acted knowingly or with gross negligence in failing to prevent the misconduct,

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2024 RPSU Agreement (SVP_EVP)

or the Committee concludes that the Participant engaged in willful fraud, embezzlement or other similar activity (including acts of omission) materially detrimental to the Company, the Company may require the Participant (or the Participant’s beneficiary) to reimburse the Company for all or any portion of the Final Award, and/or to forfeit the proceeds of any sale (including any sales to the Company) of any Company securities acquired by or on behalf of the Participant (or the Participant’s beneficiary) pursuant to the Final Award paid under this Agreement during the twelve (12) month period following the first public filing of the financial document requiring restatement, or during the twelve (12) month period following the date of the Participant’s misconduct. To the extent that the Participant is subject to the Company’s Clawback Policy, effective as of October

1, 2023, as it may be amended from time to time (the “Clawback Policy”), notwithstanding the foregoing, the Clawback Policy shall be applicable to this Agreement and any award or right

granted hereunder.

9. Committee Authority

Any question concerning the interpretation of this Agreement, any adjustments required to be made under the Plan, and any controversy that may arise under the Plan or the Grant Agreement shall be determined by the Committee in its sole discretion. Any decisions by the Committee regarding the Plan or this Agreement shall be final and binding.

10. Plan Controls

The terms of this Agreement are governed by the terms of the Plan, as it exists on the Date of the Grant and as the Plan may be amended from time to time thereafter. In the event of any conflict between the provisions of this Agreement and the provisions of the Plan, the terms of the Plan shall control.

11. Limitation on Rights; No Right to Future Grants

By entering into this Agreement, the Participant acknowledges that: (a) the Plan is discretionary and may be modified, suspended or terminated by the Company at any time, as provided in the Plan; provided that, except as provided in Section 18 of the Plan, no amendment to this Agreement shall adversely affect in a material manner the Participant’s rights hereunder without his or her written consent; (b) the grant of any award hereunder is a one-time benefit and does not create any contractual or other right to receive future grants of awards or benefits in lieu of awards; (c) all determinations with respect to any such future grants, including, but not limited to, the times when awards will be granted, the number of shares subject to each award, the award price, if any, and the time or times when each award will be settled, will be at the sole discretion of the Company; (d) participation in the Plan is voluntary; (e) the value of an award is an extraordinary item that is outside the scope of the Participant’s employment contract, if any, unless expressly provided for in any such employment contract; (f) an award is not part of normal or expected compensation for any purpose, including without limitation for calculating any benefits, severance, resignation, termination, redundancy, end of service payments, bonuses, long-service awards, pension or retirement benefits or similar payments, and the Participant will have no entitlement to compensation or damages as a consequence of any forfeiture pursuant to Section 8; (g) the future value of the Common Stock subject to the award is unknown and cannot be predicted with certainty, (h) neither the Plan, the award nor the issuance of the shares underlying the award confers upon the Participant any right to continue in the employ or service of (or any other relationship with) the Company or any Subsidiary, nor do they limit in any respect the right of the Company or any Subsidiary to terminate the Participant’s employment or other relationship with the Company or any Subsidiary, as the case may be, at any time with or without Cause, and (i) the grant of the award will not be interpreted to form an employment relationship

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2024 RPSU Agreement (SVP_EVP)

or contract with the Company or any Subsidiary.

12. General Provisions

(a) Notice

Whenever any notice is required or permitted hereunder, such notice must be in writing and delivered in person or by mail (to the address set forth below if notice is being delivered to the Company) or electronically. Any notice delivered in person or by mail shall be deemed to be delivered on the date on which it is personally delivered, or, whether actually received or not, on the third business day after it is deposited in the United States mail, certified or registered, postage prepaid, addressed to the person who is to receive it at the address set forth in this Agreement. Any notices delivered electronically shall be deemed to be delivered when transmitted and receipt is confirmed. Notices delivered to the Participant in person or by mail shall be addressed to the address for the Participant in the records of the Company. Notices delivered to the Company in person or by mail shall be addressed as follows:

Company: NRG Energy, Inc.

Attn: Talent

804 Carnegie Center

Princeton, NJ 08450

The Company or the Participant may change, by written notice to the other, the address previously specified for receiving notices.

(b) No Waiver

No waiver of any provision of this Agreement will be valid unless in writing and signed by the person against whom such waiver is sought to be enforced, nor will failure to enforce any right under this Agreement constitute a continuing waiver of the same or a waiver of any other right hereunder.

(c) Undertaking

The Participant hereby agrees to take whatever additional action, and execute whatever additional documents, the Company may deem necessary or advisable in order to carry out or effect one or more of the obligations or restrictions imposed on either the Participant or the award pursuant to the express provisions of this Agreement.

(d) Entire Contract

This Agreement and the Plan constitute the entire contract between the parties hereto with regard to the subject matter hereof. This Agreement is made pursuant to the provisions of the Plan and will in all respects be construed in conformity with the express terms and provisions of the Plan.

(e) Successors and Assigns

The provisions of this Agreement shall inure to the benefit of, and be binding on, the Company and its successors and assigns and Participant and Participant's legal representatives, heirs, legatees, distributees, assigns and transferees by operation of law.

(f) Securities Law Compliance

The Company currently has an effective registration statement on file with the Securities and

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2024 RPSU Agreement (SVP_EVP)

Exchange Commission with respect to the shares of Common Stock underlying the RPSUs awarded under this Agreement. The Company intends to maintain this registration statement but has no obligation to the Participant to do so. If the registration statement ceases to be effective, the Participant will not be able to transfer or sell shares of Common Stock issued pursuant to the award, unless exemptions from registration under applicable securities laws are available. Such exemptions from registration are very limited and might be unavailable. Participant agrees that any resale of the shares of Common Stock issued pursuant to the award shall comply in all respects with the requirements of all applicable securities laws, rules and regulations (including, without limitation, the provisions of the Securities Act of 1933, the Securities Exchange Act of

1934 and the respective rules and regulations promulgated thereunder) and any other law, rule or regulation applicable thereto, as such laws, rules, and regulations may be amended from time

to time. The Company shall not be obligated to either issue shares of Common Stock or permit

the resale of any such shares if such issuance or resale would violate any such requirements.

(g) Taxes

The Participant acknowledges that the vesting and earning of RPSUs will give rise to a withholding tax liability and that no shares of Common Stock are issuable hereunder until such withholding obligation is satisfied in full. The Participant agrees to remit to the Company the amount of any taxes required to be withheld. The Committee has specifically authorized the Participant to satisfy all or part of such tax obligation by (i) withholding the number of shares of Common Stock otherwise issuable to the Participant hereunder and/or (ii) the Participant transferring to the Company unrestricted shares of Common Stock previously owned by the Participant that have a Fair Market Value equal to the amount of the withholding to be credited. Such value shall be based on the Fair Market Value of the Common Stock as of the date the amount of tax to be withheld is determined.

(h) Governing Law

Except as may otherwise be provided in the Plan, the provisions of this Agreement shall be governed by the laws of the State of Delaware without giving effect to principles of conflicts of law.

(i) Code Section 409A Compliance

To the extent that the Committee determines that the award granted under this Agreement is subject to Section 409A of the Code and fails to comply with the requirements of such Section, notwithstanding anything to the contrary contained in the Plan or in this Agreement, the Committee reserves the right to amend, restructure, terminate or replace this award in order to cause the award to either not be subject to Section 409A of the Code or comply with the applicable provisions of such Section.

[Signature Page Follows]

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2024 RPSU Agreement (SVP_EVP)

__________________________________IN WITNESS WHEREOF, this Agreement has been executed as of the Date of Grant.

NRG ENERGY, INC.

Name:	Lawrence Coben
Title:	Interim President & CEO

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EXHIBIT A

RELATIVE TOTAL SHAREHOLDER RETURN PEER GROUP MEMBERS

The companies that make up the Standard & Poors 500 Index on the first day of the Performance Period modified in accordance with the provisions of Section 2(b) of this Agreement.

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2024 RPSU Agreement (SVP_EVP)

EX-10.24

Exhibit 10.24

NRG ENERGY, INC. LONG-TERM INCENTIVE PLAN NOTICE OF RESTRICTED STOCK UNIT GRANT

%%FIRST_NAME_LAST_NAME%-%

%%ADDRESS_LINE_1%-%

%%ADDRESS_LINE_2%-%

%%CITY_STATE_ZIPCODE%-%

Congratulations on your selection as a Participant under the NRG Energy, Inc. Amended and Restated

Long-Term Incentive Plan1 (the “Plan”). You have been chosen to receive Restricted Stock Units

(“RSUs”) under the Plan. This Notice of Restricted Stock Unit Grant (the “Grant Notice”) and the

attached Restricted Stock Unit Agreement (collectively referred to as the “Agreement”) constitute an agreement between you and NRG Energy, Inc. (the “Company”) pursuant to Section 8 of the Plan. In the event of any inconsistency between the terms of this Agreement and the terms of the Plan, the Plan’s terms shall supersede and replace the conflicting terms of this Agreement. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan. You are sometimes referred to as the “Participant” in this Agreement.

%%FIRST_NAME_LAST_NAME%-% is hereby granted RSUs as follows:

Date of Grant:	%%OPTION_DATE,’Month DD, YYYY’%-%
Vesting Commencement Date:	Date of Grant
Vesting Period:	Please refer to Section 2 of this Agreement
Total Number of RSUs:	%%TOTAL_SHARES_GRANTED,’999,999,999’%-%

Subject to Section 8 of this Agreement, if you do not remain an employee of the Company at all times during the Vesting Period, this Award shall terminate, and you will not be entitled to any Common Stock underlying the RSUs or any dividend equivalents that may have accrued with respect thereto.

If you disagree with any of the terms of this Award or choose not to accept this Award, please contact Peter Johnson at 609-524-4759 within 45 days of the Date of Grant. Otherwise, you will be deemed to have accepted this Award under the terms and conditions set forth in this Agreement and the Plan.

1 As Amended and Restated on April 27, 2017.

2024 RSU Agreement (ALL)

NRG ENERGY, INC. LONG-TERM INCENTIVE PLAN RESTRICTED STOCK UNIT AGREEMENT

This Restricted Stock Unit Agreement, dated as of the Date of Grant set forth in the Notice of Restricted Stock Unit Grant (the “Grant Notice,” and together with this Restricted Stock Unit Agreement, the “Agreement”) to which this Agreement is attached, is made between NRG Energy, Inc. (the “Company”) and the Participant, as set forth in the Grant Notice. The Grant Notice is included in, and made part of, this Agreement.

1. Grant of RSUs

Subject to the provisions of this Agreement and the provisions of the NRG Energy, Inc. Amended and Restated Long-Term Incentive Plan (the “Plan”), the Company hereby grants to the Participant the number of Restricted Stock Units (“RSUs”) set forth in the Grant Notice.

2. Vesting Schedule

Provided that you have been continuously employed by the Company during the vesting period, the RSUs will vest one-third each year beginning on the first anniversary of the Date of Grant. For the avoidance of doubt, the vesting period for the second and third portions of the RSUs begins when the previous one-third portion of the RSUs has completed vesting.

3. Conversion of RSUs and Issuance of Shares

As soon as reasonably practicable following vesting of the RSUs, subject to satisfaction of applicable tax withholding obligations in accordance with Section 12(g), the Company shall cause to be paid to the Participant one (1) share of NRG Energy, Inc. Common Stock for each RSU that vests on such vesting date, provided, however, that if the Participant incurs a Termination of Service that qualifies for vesting as described in Section 8, then such payment shall be made on the next administratively feasible regularly scheduled payroll date but at no time more than sixty (60) days after the vesting date described in the applicable subsection of Section 8, and, in accordance with Section 12(g), the Fair Market Value of the RSUs shall be determined as of such vesting date, less applicable taxes.

Notwithstanding the foregoing provisions of this Section 3 to the contrary, if at the time of the Participant’s separation from service within the meaning of Code Section 409A, the Participant is a “specified employee” within the meaning of Code Section 409A, any payment hereunder that constitutes a “deferral of compensation” under Code Section 409A and that would otherwise become due on account of such separation from service, shall be delayed, and payment shall be made in full upon the earlier of (a) a date during the thirty-day period commencing six (6) months and one (1) day following such separation from service and (b) the date of the Participant’s death.

4. Dividend Equivalent Rights

Cash dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to each RSU granted to the Participant; provided that such cash dividends shall be deemed to be reinvested in shares of Common Stock immediately following the time declared at the then Fair Market Value of the Common Stock and shall vest and be paid at the same time that the shares of Common Stock underlying the RSUs vest and are delivered to the Participant in accordance with the provisions hereof. Stock dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to each RSU granted to the Participant; provided that such stock dividends shall vest and be paid at the same time that the

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2024 RSU Agreement (ALL)

shares of Common Stock underlying the RSUs vest and are delivered to the Participant in accordance with the provisions hereof. Notwithstanding the foregoing, in the event that there are insufficient shares of Common Stock available in the Plan to settle the accrued dividends in shares of Common Stock, such shares of Common Stock shall be settled in cash in an amount equal to the Fair Market Value of such shares of Common Stock at the time of settlement. Except as otherwise provided herein, the Participant shall have no rights as a stockholder with respect to any shares of Common Stock underlying any RSU unless and until the Participant has become the holder of record of such shares.

5. Transfer of RSUs

Unless otherwise permitted by the Committee or Section 14 of the Plan, the RSUs may not be sold, transferred, pledged, assigned or otherwise alienated or hypothecated, other than pursuant to a will or the laws of descent and distribution. Any attempted disposition in violation of this Section 5 and Section 14 of the Plan shall be void.

6. Status of Participant

The Participant shall not be, and, except as otherwise provided herein, shall not have rights as, a stockholder of the Company with respect to any of the shares of Common Stock subject to this Award, unless the Award has vested and shares of Common Stock underlying the RSUs have been issued and delivered to the Participant. The Company shall not be required to issue or transfer any certificates for shares of Common Stock upon vesting of the Award until all applicable requirements of law have been complied with and such shares have been duly listed on any securities exchange on which the Common Stock may then be listed.

7. No Effect on Capital Structure

This Award shall not affect the right of the Company or any Subsidiary to reclassify, recapitalize or otherwise change its capital or debt structure or to merge, consolidate, convey any or all of its assets, dissolve, liquidate, windup, or otherwise reorganize.

8. Expiration and Forfeiture of Award

This Award shall vest and/or expire in the circumstances described in this Section 8. As used herein, “Termination of Service” means termination of a Participant’s employment by, or service to, the Company, including any of its Subsidiaries.

(a) Death

Upon a Termination of Service by reason of death, the Award shall vest in full and the Common Stock underlying the RSUs shall be issued and delivered to the Participant's legal representatives, heirs, legatees, or distributees in accordance with Section 3.

(b) Retirement

Upon a Termination of Service in the event of Retirement, the Award shall continue to vest according to the vesting schedule; provided that Retirement occurs more than twelve (12) months following the Date of Grant. Upon vesting, the Award shall be issued and delivered to the Participant in accordance with Section 3.

(c) Disability

Upon a Termination of Service as a result of Disability, the Award shall vest in full, and the Common Stock underlying the RSUs shall be issued and delivered to the Participant in accordance with Section 3.

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(d) Change in Control

Notwithstanding anything in this Section 8 to the contrary, if the Company terminates the Participant’s employment without Cause in connection with a Change in Control, the RSUs shall vest in full immediately upon the later of such Change in Control or such termination of employment. Upon vesting, the Award shall be issued and delivered to the Participant in accordance with Section 3. The Company’s termination of the Participant’s employment may be treated as being in connection with a Change in Control only if such termination occurs during the period beginning six (6) months prior to the Change in Control and ending twenty-four (24) months following the Change in Control. The Committee shall determine, in its sole and absolute discretion, whether the Participant’s employment was terminated without Cause in connection with a Change in Control.

(e) Eligible Termination

Upon a Termination of Service by reason of an Eligible Termination (as defined below), the number of RSUs that shall vest and be delivered to the Participant shall be the pro-rated percentage of the total number of RSUs awarded that is equal to the percentage of time during the aggregate vesting period for all RSUs awarded that the Participant was actually continuously employed by the Company (the “Pro-Rated Award”). The Pro-Rated Award shall vest on the fifteenth (15th) day of the month that follows the month in which the Release (as defined below) becomes irrevocable; provided, that (i) in the event the aggregate consideration and revocation period applicable to the Release spans two (2) calendar years, vesting of the Pro-Rated Award shall occur in the second calendar year; and (ii) in the event aggregate consideration and revocation period applicable to the Release ends in December, the Pro-Rated Award shall vest on December 31. Upon vesting, the Pro-Rated Award shall be issued and delivered to the Participant in accordance with Section 3.

For purposes of this Section 8(e), “Eligible Termination” means an involuntary Termination of Service in connection with the sale of a business segment, restructuring or reduction in workforce. In order to be deemed an Eligible Termination, the Participant must execute and not revoke a general release of claims in favor of the Company in a form and with terms and conditions drafted by and acceptable to the Company, which is executed, and not revoked, by the Participant as a condition to receiving the benefit described herein (the “Release”). For the avoidance of doubt: (i) an involuntary Termination of Service by reason of a Change in Control, Cause, death, or Disability is not an Eligible Termination and (ii) in the event an Eligible Termination occurs and the Award also meets the requirements for Retirement, the Award shall vest in accordance with Section 8(b). The Committee shall determine, in its sole and absolute discretion, whether a Termination of Service was by reason of an Eligible Termination.

(f) Termination of Service other than as a result of Death, Retirement, Disability, Change in Control or Eligible Termination

Upon a Termination of Service by any reason other than death, Retirement, Disability, Eligible Termination or without Cause in connection with a Change in Control, including, without limitation, as a result of retirement or disability that does not meet the requirements set forth in the definitions of such terms in the Plan, voluntary resignation or termination for Cause, any unvested portion of this Award shall expire and be forfeited to the Company.

(g) Clawback as a result of misconduct

Unless otherwise determined by the Committee, if the Company is required to prepare a material restatement of its financial statements as a result of misconduct, and the Committee determines that the Participant knowingly engaged in the misconduct, was grossly negligent with respect to such misconduct, or acted knowingly or with gross negligence in failing to prevent the misconduct, or the Committee concludes that the Participant engaged in willful fraud, embezzlement or other

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similar activity (including acts of omission) materially detrimental to the Company, the Company may require the Participant (or the Participant’s beneficiary) to reimburse the Company for all or any portion of this Award, and/or to forfeit the proceeds of any sale (including any sales to the Company) of any Company securities acquired by or on behalf of the Participant (or the Participant’s beneficiary) pursuant to the Award granted under this Agreement during the 12- month period following the first public filing of the financial document requiring restatement or during the 12-month period following the date of the Participant’s misconduct.

9. Committee Authority

Any question concerning the interpretation of this Agreement, any adjustments required to be made under the Plan, and any controversy that may arise under the Plan or this Agreement shall be determined by the Committee in its sole discretion. Any decisions by the Committee regarding the Plan or this Agreement shall be final and binding.

10. Plan Controls

The terms of this Agreement are governed by the terms of the Plan, as it exists on the Date of Grant and as the Plan may be amended from time to time thereafter. In the event of any conflict between the provisions of this Agreement and the provisions of the Plan, the terms of the Plan shall control. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan.

11. Limitation on Rights; No Right to Future Grants

By entering into this Agreement and accepting this Award, the Participant acknowledges that: (a) the Plan is discretionary and may be modified, suspended or terminated by the Company at any time, as provided in the Plan; provided that, except as provided in Section 18 of the Plan, no amendment to this Agreement shall adversely affect in a material manner the Participant’s rights under this Agreement without his or her written consent; (b) the grant of this Award is a one- time benefit and does not create any contractual or other right to receive future grants of awards or benefits in lieu of awards; (c) all determinations with respect to any such future grants, including, but not limited to, the times when awards will be granted, the number of shares subject to each award, the award price, if any, and the time or times when each award will be settled, will be at the sole discretion of the Company; (d) participation in the Plan is voluntary; (e) the value of this Award is an extraordinary item that is outside the scope of the Participant's employment contract, if any, unless expressly provided for in any such employment contract; (f) this Award is not part of normal or expected compensation for any purpose, including, without limitation, for calculating any benefits, severance, resignation, termination, redundancy, end of service payments, bonuses, long-service awards, pension or retirement benefits or similar payments, and the Participant will have no entitlement to compensation or damages as a consequence of any forfeiture of any portion of this Award pursuant to Section 8; (g) the future value of the Common Stock subject to this Award is unknown and cannot be predicted with certainty, (h) neither the Plan, this Award nor the issuance of the shares of Common Stock underlying this Award confers upon the Participant any right to continue in the employ or service of (or any other relationship with) the Company or any Subsidiary, nor do they limit in any respect the right of the Company or any Subsidiary to terminate the Participant’s employment or other relationship with the Company or any Subsidiary, as the case may be, at any time with or without Cause, and (i) the grant of this Award will not be interpreted to form an employment relationship or contract with the Company or any Subsidiary.

12. General Provisions

(a) Notice

5

2024 RSU Agreement (ALL)

Whenever any notice is required or permitted hereunder, such notice must be in writing and delivered in person or by mail (to the address set forth below if notice is being delivered to the Company) or electronically. Any notice delivered in person or by mail shall be deemed to be delivered on the date on which it is personally delivered, or, whether actually received or not, on the third business day after it is deposited in the United States mail, certified or registered, postage prepaid, addressed to the person who is to receive it at the address set forth in this Agreement. Any notice delivered electronically shall be deemed to be delivered when transmitted and receipt is confirmed. Notices delivered to the Participant in person or by mail shall be addressed to the address for the Participant in the records of the Company. Notices delivered to the Company in person or by mail shall be addressed as follows:

Company: NRG Energy, Inc.

Attn: Talent

804 Carnegie Center

Princeton, NJ 08450

The Company or the Participant may change, by written notice to the other, the address previously specified for receiving notices.

(b) No Waiver

No waiver of any provision of this Agreement will be valid unless in writing and signed by the person against whom such waiver is sought to be enforced, nor will failure to enforce any right under this Agreement constitute a continuing waiver of the same or a waiver of any other right hereunder.

(c) Undertaking

The Participant hereby agrees to take whatever additional action, and execute whatever additional documents, the Company may deem necessary or advisable in order to carry out or effect one or more of the obligations or restrictions imposed on either the Participant or the Award pursuant to the express provisions of this Agreement.

(d) Entire Contract

This Agreement and the Plan constitute the entire contract between the parties hereto with regard to the subject matter hereof. This Agreement is made pursuant to the provisions of the Plan and will, in all respects, be construed in conformity with the express terms and provisions of the Plan.

(e) Successors and Assigns

The provisions of this Agreement shall inure to the benefit of, and be binding on, the Company and its successors and assigns and Participant and Participant's legal representatives, heirs, legatees, distributees, assigns and transferees by operation of law.

(f) Securities Law Compliance

The Company currently has an effective registration statement on file with the Securities and Exchange Commission with respect to the shares of Common Stock underlying this Award. The Company intends to maintain this registration statement but has no obligation to the Participant to do so. If the registration statement ceases to be effective, the Participant will not be able to transfer or sell shares of Common Stock issued pursuant to this Award, unless exemptions from registration under applicable securities laws are available. Such exemptions from registration are very limited and might be unavailable. Participant agrees that any resale of the shares of Common Stock issued pursuant to this Award shall comply in all respects with the requirements of all applicable securities laws, rules and regulations (including, without limitation, the provisions

6

2024 RSU Agreement (ALL)

of the Securities Act of 1933, the Securities Exchange Act of 1934 and the respective rules and regulations promulgated thereunder) and any other law, rule or regulation applicable thereto, as such laws, rules, and regulations may be amended from time to time. The Company shall not be obligated to either issue shares of Common Stock or permit the resale of any such shares if such issuance or resale would violate any such requirements.

(g) Taxes

The Participant acknowledges that the vesting and earning of the RSUs will give rise to a withholding tax liability and that no shares of Common Stock are issuable hereunder until such withholding obligation is satisfied in full. The Participant agrees to remit to the Company the amount of any taxes required to be withheld. The Committee has specifically authorized the Participant to satisfy all or part of such tax obligation by (i) withholding the number of shares of Common Stock otherwise issuable to the Participant hereunder and/or (ii) the Participant transferring to the Company unrestricted shares of Common Stock previously owned by the Participant that have a Fair Market Value equal to the amount of the withholding to be credited. Such value shall be based on the Fair Market Value of the Common Stock as of the date the amount of tax to be withheld is determined.

(h) Governing Law

Except as may otherwise be provided in the Plan, the provisions of this Agreement shall be governed by the laws of the State of Delaware without giving effect to principles of conflicts of law.

(i) Code Section 409A Compliance

To the extent that the Committee determines that the Award granted under this Agreement is subject to Section 409A of the Code and fails to comply with the requirements of such Section, notwithstanding anything to the contrary contained in the Plan or in this Agreement, the Committee reserves the right to amend, restructure, terminate or replace this Award in order to cause the Award to either not be subject to Section 409A of the Code or comply with the applicable provisions of such Section.

[Signature Page Follows]

7

2024 RSU Agreement (ALL)

IN WITNESS WHEREOF, this Agreement has been executed as of the Date of Grant.

NRG ENERGY, INC.

Name:	Lawrence Coben
Title:	Interim President & CEO

8

2024 RSU Agreement (ALL)

EX-10.25

Exhibit 10.25

NRG ENERGY, INC. LONG-TERM INCENTIVE PLAN NOTICE OF RESTRICTED STOCK UNIT GRANT

%%FIRST_NAME_LAST_NAME%-%

%%ADDRESS_LINE_1%-%

%%ADDRESS_LINE_2%-%

%%CITY_STATE_ZIPCODE%-%

Congratulations on your selection as a Participant under the NRG Energy, Inc. Amended and Restated

Long-Term Incentive Plan1 (the “Plan”). You have been chosen to receive Restricted Stock Units

(“RSUs”) under the Plan. This Notice of Restricted Stock Unit Grant (the “Grant Notice”) and the

attached Restricted Stock Unit Agreement (collectively referred to as the “Agreement”) constitute an agreement between you and NRG Energy, Inc. (the “Company”) pursuant to Section 8 of the Plan. In the event of any inconsistency between the terms of this Agreement and the terms of the Plan, the Plan’s terms shall supersede and replace the conflicting terms of this Agreement. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan. You are sometimes referred to as the “Participant” in this Agreement.

%%FIRST_NAME_LAST_NAME%-% is hereby granted RSUs as follows:

Date of Grant:	%%OPTION_DATE,’Month DD, YYYY’%-%
Vesting Commencement Date:	December 15, 2023
Vesting Period:	Please refer to Section 2 of this Agreement
Total Number of RSUs:	%%TOTAL_SHARES_GRANTED,’999,999,999’%-%

Subject to Section 8 of this Agreement, if you do not remain an employee of the Company at all times during the Vesting Period, this Award shall terminate, and you will not be entitled to any Common Stock underlying the RSUs or any dividend equivalents that may have accrued with respect thereto.

If you disagree with any of the terms of this Award or choose not to accept this Award, please contact Peter Johnson at 609-524-4759 within 45 days of the Date of Grant. Otherwise, you will be deemed to have accepted this Award under the terms and conditions set forth in this Agreement and the Plan.

1 As Amended and Restated on April 27, 2017.

NRG ENERGY, INC. LONG-TERM INCENTIVE PLAN RESTRICTED STOCK UNIT AGREEMENT

This Restricted Stock Unit Agreement, dated as of the Date of Grant set forth in the Notice of Restricted Stock Unit Grant (the “Grant Notice,” and together with this Restricted Stock Unit Agreement, the “Agreement”) to which this Agreement is attached, is made between NRG Energy, Inc. (the “Company”) and the Participant, as set forth in the Grant Notice. The Grant Notice is included in, and made part of, this Agreement.

1. Grant of RSUs

Subject to the provisions of this Agreement and the provisions of the NRG Energy, Inc. Amended and Restated Long-Term Incentive Plan (the “Plan”), the Company hereby grants to the Participant the number of Restricted Stock Units (“RSUs”) set forth in the Grant Notice.

2. Vesting Schedule

The vesting period shall end on the first anniversary of the Vesting Commencement Date. Provided that Participant has been continuously employed by the Company as the Interim CEO during the vesting period, 100% of the RSUs will vest upon the completion of the vesting period. In the event you experience a Termination of Service during the vesting period, your RSUs shall vest in accordance with the terms of Section 8.

3. Conversion of RSUs and Issuance of Shares

Subject to satisfaction of applicable tax withholding obligations in accordance with Section 12(g), the Company shall cause to be paid to the Participant one (1) share of NRG Energy, Inc. Common Stock for each vested RSU in respect of one-third of the total vested RSUs on, or as soon as practicable following, each of first three anniversaries of the Vesting Commencement Date.

Notwithstanding the foregoing provisions of this Section 3 to the contrary, if at the time of the Participant’s separation from service within the meaning of Code Section 409A, the Participant is a “specified employee” within the meaning of Code Section 409A, any payment hereunder that constitutes a “deferral of compensation” under Code Section 409A and that would otherwise become due on account of such separation from service, shall be delayed, and payment shall be made in full upon the earlier of (a) a date during the thirty-day period commencing six (6) months and one (1) day following such separation from service and (b) the date of the Participant’s death. Each installment payable hereunder shall constitute a separate payment.

4. Dividend Equivalent Rights

Cash dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to each RSU granted to the Participant; provided that such cash dividends shall be deemed to be reinvested in shares of Common Stock immediately following the time declared at the then Fair Market Value of the Common Stock and shall vest and be paid at the same time that the shares of Common Stock underlying the RSUs vest and are delivered to the Participant in accordance with the provisions hereof. Stock dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to each RSU granted to the Participant; provided that such stock dividends shall vest and be paid at the same time that the shares of Common Stock underlying the RSUs vest and are delivered to the Participant in accordance with the provisions hereof. Notwithstanding the foregoing, in the event that there are insufficient shares of Common Stock available in the Plan to settle the accrued dividends in

2

shares of Common Stock, such shares of Common Stock shall be settled in cash in an amount equal to the Fair Market Value of such shares of Common Stock at the time of settlement. Except as otherwise provided herein, the Participant shall have no rights as a stockholder with respect to any shares of Common Stock underlying any RSU unless and until the Participant has become the holder of record of such shares.

5. Transfer of RSUs

Unless otherwise permitted by the Committee or Section 14 of the Plan, the RSUs may not be sold, transferred, pledged, assigned or otherwise alienated or hypothecated, other than pursuant to a will or the laws of descent and distribution. Any attempted disposition in violation of this Section 5 and Section 14 of the Plan shall be void.

6. Status of Participant

The Participant shall not be, and, except as otherwise provided herein, shall not have rights as, a stockholder of the Company with respect to any of the shares of Common Stock subject to this Award, unless the Award has vested and shares of Common Stock underlying the RSUs have been issued and delivered to the Participant. The Company shall not be required to issue or transfer any certificates for shares of Common Stock upon vesting of the Award until all applicable requirements of law have been complied with and such shares have been duly listed on any securities exchange on which the Common Stock may then be listed.

7. No Effect on Capital Structure

This Award shall not affect the right of the Company or any Subsidiary to reclassify, recapitalize or otherwise change its capital or debt structure or to merge, consolidate, convey any or all of its assets, dissolve, liquidate, windup, or otherwise reorganize.

8. Expiration and Forfeiture of Award

This Award shall vest and/or expire in the circumstances described in this Section 8. As used herein, “Termination of Service” means termination of a Participant’s employment by, or service to, the Company as Interim CEO; provided, however, in respect of any payment hereunder that constitutes a “deferral of compensation” under Code Section 409A that is payable upon the Participant’s termination of employment with the Company, a Termination of Service shall be deemed to have occurred only unless and until the Participant has also incurred a “separation from service” under Code Section 409A.

(a) Death

Upon a Termination of Service by reason of death, the Award shall vest in full and the Common Stock underlying the RSUs shall be issued and delivered to the Participant's legal representatives, heirs, legatees, or distributees as soon as practicable following such the Participant’s death.

(b) Disability

Upon the Participant’s Disability, the Award shall vest in full, and the Common Stock underlying the RSUs shall be issued and delivered to the Participant as soon as practicable following such the Participant’s. For purposes of this Agreement, Disability shall have the meaning ascribed thereto in Section 1.409A-3(i)(4) of the treasury regulations.

(c) Change in Control

Notwithstanding anything in this Section 8 to the contrary, if the Company terminates the

Participant’s employment without Cause in connection with a Change in Control, the RSUs shall

3

vest in full immediately and be payable immediately upon the later of such Change in Control or such termination of employment. The Company’s termination of the Participant’s employment may be treated as being in connection with a Change in Control only if such termination occurs during the period beginning six (6) months prior to the Change in Control and ending twenty- four (24) months following the Change in Control. Subject to the requirements of Section 409A of the Code, the Committee shall determine, in its sole and absolute discretion, whether the Participant’s employment was terminated without Cause in connection with a Change in Control.

(d) Eligible Termination

Upon a Termination of Service by reason of an Eligible Termination (as defined below), the number of RSUs that shall vest shall be the pro-rated percentage of the total number of RSUs awarded that is equal to the percentage of time during the aggregate vesting period for all RSUs awarded that the Participant was actually continuously employed by the Company (the “Pro-Rated Award”). Upon vesting, the Pro-Rated Award shall be issued and delivered to the Participant in accordance with Section 3.

For purposes of this Section 8(e), “Eligible Termination” means any Termination of Service other than by the Company for Cause.

(e) Termination of Service for Cause

Upon a Termination of Service by the Company for Cause, any portion of this Award that is unvested or has not been converted to Common Stock and delivered to the Participant shall expire and be forfeited to the Company.

(f) Clawback as a result of misconduct

Unless otherwise determined by the Committee, if the Company is required to prepare a material restatement of its financial statements as a result of misconduct, and the Committee determines that the Participant knowingly engaged in the misconduct, was grossly negligent with respect to such misconduct, or acted knowingly or with gross negligence in failing to prevent the misconduct, or the Committee concludes that the Participant engaged in willful fraud, embezzlement or other similar activity (including acts of omission) materially detrimental to the Company, the Company may require the Participant (or the Participant’s beneficiary) to reimburse the Company for all or any portion of this Award, and/or to forfeit the proceeds of any sale (including any sales to the Company) of any Company securities acquired by or on behalf of the Participant (or the Participant’s beneficiary) pursuant to the Award granted under this Agreement during the 12- month period following the first public filing of the financial document requiring restatement or during the 12-month period following the date of the Participant’s misconduct.

9. Committee Authority

Any question concerning the interpretation of this Agreement, any adjustments required to be made under the Plan, and any controversy that may arise under the Plan or this Agreement shall be determined by the Committee in its sole discretion. Any decisions by the Committee regarding the Plan or this Agreement shall be final and binding.

10. Plan Controls

The terms of this Agreement are governed by the terms of the Plan, as it exists on the Date of Grant and as the Plan may be amended from time to time thereafter. In the event of any conflict between the provisions of this Agreement and the provisions of the Plan, the terms of the Plan shall control. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan.

4

11. Limitation on Rights; No Right to Future Grants

By entering into this Agreement and accepting this Award, the Participant acknowledges that: (a) the Plan is discretionary and may be modified, suspended or terminated by the Company at any time, as provided in the Plan; provided that, except as provided in Section 18 of the Plan, no amendment to this Agreement shall adversely affect in a material manner the Participant’s rights under this Agreement without his or her written consent; (b) the grant of this Award is a one- time benefit and does not create any contractual or other right to receive future grants of awards or benefits in lieu of awards; (c) all determinations with respect to any such future grants, including, but not limited to, the times when awards will be granted, the number of shares subject to each award, the award price, if any, and the time or times when each award will be settled, will be at the sole discretion of the Company; (d) participation in the Plan is voluntary; (e) the value of this Award is an extraordinary item that is outside the scope of the Participant's employment contract, if any, unless expressly provided for in any such employment contract; (f) this Award is not part of normal or expected compensation for any purpose, including, without limitation, for calculating any benefits, severance, resignation, termination, redundancy, end of service payments, bonuses, long-service awards, pension or retirement benefits or similar payments, and the Participant will have no entitlement to compensation or damages as a consequence of any forfeiture of any portion of this Award pursuant to Section 8; (g) the future value of the Common Stock subject to this Award is unknown and cannot be predicted with certainty, (h) neither the Plan, this Award nor the issuance of the shares of Common Stock underlying this Award confers upon the Participant any right to continue in the employ or service of (or any other relationship with) the Company or any Subsidiary, nor do they limit in any respect the right of the Company or any Subsidiary to terminate the Participant’s employment or other relationship with the Company or any Subsidiary, as the case may be, at any time with or without Cause, and (i) the grant of this Award will not be interpreted to form an employment relationship or contract with the Company or any Subsidiary.

12. General Provisions

(a) Notice

Whenever any notice is required or permitted hereunder, such notice must be in writing and delivered in person or by mail (to the address set forth below if notice is being delivered to the Company) or electronically. Any notice delivered in person or by mail shall be deemed to be delivered on the date on which it is personally delivered, or, whether actually received or not, on the third business day after it is deposited in the United States mail, certified or registered, postage prepaid, addressed to the person who is to receive it at the address set forth in this Agreement. Any notice delivered electronically shall be deemed to be delivered when transmitted and receipt is confirmed. Notices delivered to the Participant in person or by mail shall be addressed to the address for the Participant in the records of the Company. Notices delivered to the Company in person or by mail shall be addressed as follows:

Company: NRG Energy, Inc.

Attn: Talent

804 Carnegie Center

Princeton, NJ 08450

The Company or the Participant may change, by written notice to the other, the address previously specified for receiving notices.

(b) No Waiver

No waiver of any provision of this Agreement will be valid unless in writing and signed by the person against whom such waiver is sought to be enforced, nor will failure to enforce any right

5

under this Agreement constitute a continuing waiver of the same or a waiver of any other right hereunder.

(c) Undertaking

The Participant hereby agrees to take whatever additional action, and execute whatever additional documents, the Company may deem necessary or advisable in order to carry out or effect one or more of the obligations or restrictions imposed on either the Participant or the Award pursuant to the express provisions of this Agreement.

(d) Entire Contract

This Agreement and the Plan constitute the entire contract between the parties hereto with regard to the subject matter hereof. This Agreement is made pursuant to the provisions of the Plan and will, in all respects, be construed in conformity with the express terms and provisions of the Plan.

(e) Successors and Assigns

The provisions of this Agreement shall inure to the benefit of, and be binding on, the Company and its successors and assigns and Participant and Participant's legal representatives, heirs, legatees, distributees, assigns and transferees by operation of law.

(f) Securities Law Compliance

The Company currently has an effective registration statement on file with the Securities and Exchange Commission with respect to the shares of Common Stock underlying this Award. The Company intends to maintain this registration statement but has no obligation to the Participant to do so. If the registration statement ceases to be effective, the Participant will not be able to transfer or sell shares of Common Stock issued pursuant to this Award, unless exemptions from registration under applicable securities laws are available. Such exemptions from registration are very limited and might be unavailable. Participant agrees that any resale of the shares of Common Stock issued pursuant to this Award shall comply in all respects with the requirements of all applicable securities laws, rules and regulations (including, without limitation, the provisions of the Securities Act of 1933, the Securities Exchange Act of 1934 and the respective rules and regulations promulgated thereunder) and any other law, rule or regulation applicable thereto, as such laws, rules, and regulations may be amended from time to time. The Company shall not be obligated to either issue shares of Common Stock or permit the resale of any such shares if such issuance or resale would violate any such requirements.

(g) Taxes

The Participant acknowledges that the vesting and earning of the RSUs will give rise to a withholding tax liability and that no shares of Common Stock are issuable hereunder until such withholding obligation is satisfied in full. The Participant agrees to remit to the Company the amount of any taxes required to be withheld. The Committee has specifically authorized the Participant to satisfy all or part of such tax obligation by (i) withholding the number of shares of Common Stock otherwise issuable to the Participant hereunder and/or (ii) the Participant transferring to the Company unrestricted shares of Common Stock previously owned by the Participant that have a Fair Market Value equal to the amount of the withholding to be credited. Such value shall be based on the Fair Market Value of the Common Stock as of the date the amount of tax to be withheld is determined.

(h) Governing Law

6

Except as may otherwise be provided in the Plan, the provisions of this Agreement shall be governed by the laws of the State of Delaware without giving effect to principles of conflicts of law.

(i) Code Section 409A Compliance

To the extent that the Committee determines that the Award granted under this Agreement is subject to Section 409A of the Code and fails to comply with the requirements of such Section, notwithstanding anything to the contrary contained in the Plan or in this Agreement, the Committee reserves the right to amend, restructure, terminate or replace this Award in order to cause the Award to either not be subject to Section 409A of the Code or comply with the applicable provisions of such Section.

[Signature Page Follows]

7

IN WITNESS WHEREOF, this Agreement has been executed as of the Date of Grant.

NRG ENERGY, INC.

Name:	Brian Curci
Title:	EVP, Legal

8

EX-10.29

Exhibit 10.29

VIVINT SMART HOME, INC. LONG-TERM INCENTIVE PLAN NOTICE OF RELATIVE PERFORMANCE STOCK UNITS

/$ParticipantName$/

/$ParticipantAddress$/

Congratulations on your selection as a Participant under the Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan (“Plan”). This Notice of Relative Performance Stock Units (the “Grant Notice”) and the attached Relative Performance Stock Unit Agreement (collectively referred to as the “Agreement”) constitute an agreement between you and NRG Energy, Inc. (the “Company”) pursuant to Section 9 of the Plan. In the event of any inconsistency between the terms of this Agreement and the terms of the Plan, the Plan’s terms shall supersede and replace the conflicting terms of this Agreement. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan. You are sometimes referred to as the “Participant” in this Agreement.

/$ParticipantName$/ is hereby granted Relative Performance Stock Units (“RPSUs”) as follows:

Date of Grant:	/$GrantDate$/
Performance Period:	January 2, 2024 through January 2, 2027
Target Award:	/$AwardsGranted$/
Final Award:	Target Award multiplied by “Payout Percentage” based on the Company’s total shareholder return relative to total shareholder return of peer group members of the Standard & Poors 500 Index, as set forth in this Agreement.

Payment of the Final Award shall be made in NRG Energy, Inc. Common Stock and shall be made no earlier than January 2, 2027 and no later than March 15, 2027, but in no event later than two and a half months following the end of the calendar year in which the Final Award vested in compliance with the short-term deferral exception of IRC Section 409A.

Subject to Section 8 of this Agreement, if your employment by, or service to, the Company is terminated at any time during the Performance Period, any award or right granted hereunder shall expire and be forfeited, and no Final Award or dividend equivalent related thereto shall be paid.

If you disagree with any of the terms of this award or choose not to accept this award, please contact Peter Johnson at 609-524-4759 within 45 days of the Date of Grant. Otherwise, you will be deemed to have accepted this award under the terms and conditions set forth in this Agreement and the Plan.

LEGAL\61899936\12

VIVINT SMART HOME, INC. LONG-TERM INCENTIVE PLAN RELATIVE PERFORMANCE STOCK UNIT AGREEMENT

This Relative Performance Stock Unit Agreement, dated as of the Date of Grant set forth in the Notice of Relative Performance Stock Units (the “Grant Notice,” and together with this Relative Performance Stock Unit Agreement, the “Agreement”) to which this Agreement is attached, is made between NRG Energy, Inc. (the “Company”) and the Participant, as set forth in the Grant Notice. The Grant Notice is included in, and made part of, this Agreement.

1.Performance Criteria and Award Determination

(a)General - Award Determination

Subject to the provisions of this Agreement and the provisions of the Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan (the “Plan”), the Company hereby grants to the Participant the number of Relative Performance Stock Units (“RPSUs”), set forth in the Grant Notice (“Target Award”), each of which will have a value equivalent to one (1) share of the Company’s Common Stock.

At the end of the Performance Period, the Participant shall be entitled to receive a payment, payable in shares of the Company’s Common Stock, equal to the Target Award times a “Payout Percentage” (the “Final Award”); provided, that if the Fair Market Value of the payment due to the Participant in satisfaction of the Final Award is greater than the amount that is six (6) times the Fair Market Value of the Target Award, determined as of the Date of Grant (the “Cap”), the Payout Percentage shall be adjusted such that Fair Market Value of such payment does not exceed the Cap. The “Payout Percentage” is based on the achievement of the performance criteria set forth in Section 1(b) of this Agreement, as determined and certified in writing by the Compensation Committee of the Company’s Board of Directors (the “Committee”).

(b)Performance Criteria and Relative TSR Comparison

Except as provided in Section 8 of this Agreement, a “Payout Percentage” is used to determine the Final Award under this Agreement. Subject to Section 1(c) of this Agreement, the “Payout Percentage” shall be based upon the Company’s total shareholder return (“TSR”) percentile ranking, as determined pursuant to Section 2 of this Agreement, and the Company’s TSR percentile ranking relative to “Chart A” below.

Chart A
TSR Performance Relative to Companies in the Peer Group	Payout Percentage (% of Target)
75th Percentile or Above	200%
55th Percentile - TARGET	100%
25th Percentile	25%
Below the 25th Percentile	0%

(c)Relative TSR Comparison if absolute TSR of Company is less than negative 15%

Notwithstanding the foregoing, if the Company’s absolute TSR for the Performance Period is less than negative fifteen percent (-15%), the Final Award will be based on the following chart.

2

LEGAL\61899936\12

Chart B
TSR Performance Relative to Companies in Peer Group	Payout (% of Target)
75th Percentile or Above	200%
65th Percentile - TARGET	100%
25th Percentile	25%
Below the 25th Percentile	0%

2.Measuring Performance and relative TSR Ranking

(a)Performance Measure and RPSUs

For purposes of determining the Final Award, as soon as practicable after the completion of the Performance Period, (i) the TSRs of the Company and the companies set forth on Exhibit A, which comprise the peer group for purposes of this Agreement (each company is referred to as a “Peer Group Member”), shall be calculated pursuant to Section 2(d) and (ii) the relative ranking of the Company’s TSR for the Performance Period, as compared to the TSR for each Peer Group Member for the Performance Period, shall be determined and expressed as a percentile ranking as described in Section 2(b).

(b)Total Shareholder Percentile Ranking

The Company’s TSR percentile ranking is based on the TSR to the Company’s stockholders during the Performance Period, inclusive of dividends paid, relative to the TSR during the Performance Period, inclusive of dividends paid, achieved by each of the Peer Group Members.

The Company’s TSR percentile ranking shall be determined as follows: the TSR percentile ranking shall be determined by ranking ranking the Company and each of the Peer Group Members from highest to lowest according to their respective TSRs. After this ranking, the percentile performance of the Company relative to the Peer Group Members will be determined as follows:

P=1 – R-1
N-1

where:    “P” represents the percentile performance

        “N” represents the number of Peer Group Members, including the Company, as of the vesting date.

“R” represents the Company’s ranking among the Peer Group Members.

i.In the event a bankruptcy proceeding is commenced during the Performance Period with respect to any Peer Group Member, or if at any time during the Performance Period a Peer Group Member is liquidated or delisted, such company shall be treated as having a TSR of negative one hundred (-100%) for the Performance Period for purposes of TSR percentile ranking.

ii.In the event that a merger, acquisition or business combination of a Peer Group Member by or with another Peer Group Member is consummated during the Performance Period, then the entity that survives as a result of such merger, acquisition, or business combination will be considered a Peer Group Member for purposes of TSR percentile ranking for the Performance Period; the Peer Group Member that is not the entity that survives as a result of such merger, acquisition or business combination, shall be removed and treated as if it had never been in the peer group for purposes of the TSR percentile ranking for the Performance Period.

iii.In the event that a merger, acquisition or business combination of a Peer Group Member by or with an entity that is not a Peer Group Member is consummated during the

3

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Performance Period, and such Peer Group Member is the entity that survives as a result of such merger, acquisition, or business combination, then such Peer Group Member will continue to be considered a Peer Group Member for purposes of TSR percentile ranking for the Performance Period.

iv.In the event that (i) a Peer Group Member ceases to be a publicly-traded company, or (ii) a merger, acquisition or business combination of a Peer Group Member by or with an entity that is not Peer Group Member is consummated during the Performance Period, and such Peer Group Member is not the entity that survives as a result of such merger, acquisition, or business combination, then such Peer Group Member shall be removed and treated as if it had never been in the peer group for purposes of TSR percentile ranking for the Performance Period.

v.In the event of a distribution of stock from a Peer Group Member (including the Company) consisting of shares of a new publicly traded company (a “spin-off”), the Peer Group Member shall remain a Peer Group Member and the stock distribution will be treated as a dividend from the Peer Group Member (including the Company) based on the closing price of the shares of the spin-off company on its first day of trading. The performance of the shares of the spin-off company shall not thereafter be treated for purposes of calculating TSR.

(c)Performance Period

The Performance Period, for purposes of this Agreement, shall be determined by the Compensation Committee and shall be the period set forth in the Grant Notice.

(d)Performance Goal and TSR

For purposes of this Agreement, TSR for the Company and each of the Peer Group Members shall be measured by dividing (A) the difference between the average closing price of a share of such company’s common stock on the principal exchange on which such stock trades for the twenty (20) trading days occurring immediately prior to and including the first day of the Performance Period (the “Beginning Average Value”) including the impact of dividends that are reinvested on the ex-dividend date and the average closing price of a share of such stock on the principal exchange on which such stock trades for the twenty (20) trading days immediately prior to and including the last day of the Performance Period (the “Ending Average Value”) (appropriately adjusted for any stock dividend, stock split, spin-off, merger or other similar corporate events affecting such stock) including the impact of dividends that are reinvested on the ex-dividend date, by (B) the Beginning Average Value.

For the avoidance of doubt, it is intended that the foregoing calculation of TSR shall take into account not only the reinvestment of dividends in a share of common stock of the Company or any Peer Group Member, as applicable, but also capital appreciation or depreciation in the shares deemed acquired by such reinvestment. All determinations under this Section 2(d) shall be made by the Committee.

Illustration of formula described above
Total Shareholder Return	=	Ending Average Value - Beginning Average Value Beginning Average Value

3.Settlement of Final Award

As soon as reasonably practicable following completion of all determinations and certifications contemplated by Sections 1 and 2, but in no event later than March 15 of the year following the year in which the Performance Period ends,subject to satisfaction of applicable tax withholding obligations in accordance with Section 12(g), the Company shall cause to be paid to the Participant the number of shares of the Company’s Common Stock equal to the product of the number of RPSUs representing the Final Award, as determined under Section 1 of this Agreement, multiplied by the Fair Market Value of a share of Common Stock as of the last trading day of the Performance Period, provided, however, that if the Participant incurs a

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Termination of Service that qualifies for payment of a Final Award as described in Section 8, then such payment shall be made on the next administratively feasible regularly scheduled payroll date but at no time more than sixty (60) days after the date a Final Award, if any, is determined or becomes payable, as described in the applicable subsection of Section 8, and, in accordance with Section 12(g), the Fair Market Value of the RPSUs shall be determined as of such date, less applicable taxes.

Notwithstanding the foregoing provisions of this Section 3 to the contrary, if at the time of the Participant’s separation from service within the meaning of Code Section 409A, the Participant is a “specified employee” within the meaning of Code Section 409A, any payment hereunder that constitutes a “deferral of compensation” under Code Section 409A and that would otherwise become due on account of such separation from service shall be delayed, and payment shall be made in full upon the earlier of (a) a date during the thirty (30) day period commencing six (6) months and one (1) day following such separation from service and (b) the date of the Participant’s death.

4.Dividend Equivalent Rights

Cash dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to the Target Award; provided that such cash dividends shall be deemed to be reinvested in shares of Common Stock immediately following the time declared at the then Fair Market Value of the Common Stock and shall be paid at the same time that the Final Award is delivered to the Participant in accordance with the provisions hereof. Stock dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to the Target Award; provided that such stock dividends shall be paid at the same time that the Final Award is delivered to the Participant in accordance with the provisions hereof. Notwithstanding the foregoing, in the event that there are insufficient shares of Common Stock available in the Plan to settle the accrued dividend book entry account in shares of Common Stock, such accrued book entry account shall be settled in cash in an amount equal to the Fair Market Value of such shares of Common Stock at the time of settlement. Except as otherwise provided herein, the Participant shall have no rights as a stockholder with respect to any shares of Common Stock underlying any RPSU unless and until the Participant has become the holder of record of such shares.

5.Transfer of RPSUs

Unless otherwise permitted by the Committee or Section 13 of the Plan, no award or right granted hereunder may be sold, transferred, pledged, assigned or otherwise alienated or hypothecated, other than pursuant to a will or the laws of descent and distribution. Any attempted disposition in violation of this Section 5 and Section 13 of the Plan shall be void.

6.Status of Participant

The Participant shall not be, and, except as otherwise provided herein, shall not have rights as, a stockholder of the Company with respect to any of the shares of Common Stock subject to, or underlying, the Target Award or Final Award, unless such shares have been issued and delivered to the Participant pursuant to the terms of this Agreement. The Company shall not be required to issue or transfer any certificates for shares of Common Stock until all applicable requirements of law have been complied with and such shares have been duly listed on any securities exchange on which the Common Stock may then be listed.

7.No Effect on Capital Structure

No award or right granted hereunder shall affect the right of the Company or any Subsidiary to reclassify, recapitalize or otherwise change its capital or debt structure or to merge, consolidate, convey any or all of its assets, dissolve, liquidate, windup, or otherwise reorganize.

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8.Expiration and Forfeiture of Award

The Final Award, if any, shall be paid and/or expire in the circumstances described in this Section 8. As used herein, “Termination of Service” means termination of a Participant’s employment by, or service to, the Company, including any of its Subsidiaries.

(a)Death

Upon a Termination of Service by reason of death, a Final Award equal to one hundred percent (100%) of the Target Award shall be paid to the Participant’s legal representatives, heirs, legatees, or distributees in accordance with Section 3.

(b)Retirement

Retirement means (i) for any non-director, unless otherwise determined by the Committee, means (A) termination of service as a non-director after at least 10 years of service by such non-director and (B) attaining at least 55 years of age, and (ii) for any director, unless otherwise determined by the Committee, means termination of service as a director after at least five years of Board service by such director.

Upon a Termination of Service in the event of Retirement, the Award shall continue to vest according to the vesting schedule; provided that Retirement occurs more than twelve (12) months following the Date of Grant. Upon vesting, the Award shall be issued and delivered to the Participant in accordance with Sections 1 and 2, and any such Final Award shall be paid to the Participant in accordance with Section 3.

(c)Disability

Upon a Termination of Service as a result of Disability, a Final Award equal to one hundred percent (100%) of the Target Award shall be paid to the Participant in accordance with Section 3. For purposes of this Agreement, “Disability” means a disability that would entitle an eligible Participant to payment of monthly disability payments under any Company long-term disability plan or as otherwise determined by the Committee.

(d)Change in Control

Notwithstanding any provision in this Section 8 to the contrary, if the Company terminates the Participant’s employment without Cause in connection with a Change in Control (other than the Merger, as hereinafter defined), the Final Award payable to the Participant, if any, shall be determined by the Committee and shall be paid to the Participant in accordance with Section 3. The Company’s termination of the Participant’s employment may be treated as being in connection with a Change in Control only if such termination occurs during the period beginning six (6) months prior to the Change in Control and ending twenty-four (24) months following the Change in Control.

(e) Eligible Termination

Upon a Termination of Service by reason of an Eligible Termination (as defined below), the Participant shall continue to be eligible to receive a Final Award, if any, as though the Participant was continuously employed by the Company throughout the Performance Period. At the end of the Performance Period, the Company will determine the Final Award that the Participant would have received had the Participant been continuously employed by the Company throughout the Performance Period in accordance with Sections 1 and 2 (the “Performance Award”). The Performance Award shall then be pro-rated such that the total number of shares of Common Stock paid to the Participant shall be the percentage of the Performance Award that is equal to the percentage of time that the Participant was actually continuously employed by the Company during the Performance Period (the “Pro-rated Performance Award”). The Pro-rated Performance Award shall become payable to the Participant on the later to occur of (A) the date that the Final Award would have be delivered in accordance with Section 3 had the Participant been continuously employed by the Company throughout the Performance Period, and (B) on or about the fifteenth (15th) day of the month that follows the month in which the Release (as defined below) becomes irrevocable; provided, that (i) in the event the aggregate consideration and revocation period applicable to the Release spans two (2) calendar years, the applicable date under this Clause (B) will be on or about January 15 of the second calendar year and, (ii) in the event the aggregate consideration and

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revocation period applicable to the Release ends in December, the applicable date under this Clause (B) will be on or before the last day of that month of December. Upon becoming payable, the Pro-rated Performance Award shall be paid to the Participant in accordance with Section 3.

For purposes of this Section 8(e), “Eligible Termination” means an involuntary Termination of Service in connection with the sale of a business segment, restructuring or reduction in workforce. In order to be deemed an Eligible Termination, the Participant must execute and not revoke a general release of claims in favor of the Company in a form and with terms and conditions drafted by and acceptable to the Company, which is executed, and not revoked, by the Participant as a condition to receiving the benefit described herein (the “Release”). For the avoidance of doubt: (i) an involuntary Termination of Service by reason of a Change in Control, Cause, death, Disability, Good Reason, or not for Cause is not an Eligible Termination and (ii) in the event an Eligible Termination occurs and the Participant also meets the requirements for Retirement, the Award shall be paid in accordance with Section 8(b).

(e)Termination of Service other than as a result of Death, Retirement, Disability, or Change in Control

Except as provided in Section 8(h), upon a Termination of Service by any reason other than death, Retirement, Disability or without Cause in connection with a Change in Control, including, without limitation, as a result of retirement or disability that does not meet the requirements set forth in the definitions of such terms in the Plan or this Agreement, any award or right granted hereunder shall expire and be forfeited, and no Final Award or dividend equivalent related thereto shall be paid.

(f)Clawback/Repayment

All RPSUs shall be subject to reduction, cancellation, forfeiture, or recoupment to the extent necessary to comply with (i) any clawback, forfeiture, or other similar policy adopted by the Board or the Committee and is in effect from time to time and (ii) applicable law. Further, unless otherwise determined by the Committee, to the extent that the Participant receives any amount in excess of the amount that the Participant should otherwise have received under the terms of the Award for any reason (including, without limitation, by reason of a financial restatement, mistake in calculations or other administrative error), the Participant shall be required to repay any such excess amount to the Company. To the extent that the Participant is subject to the Company’s Clawback Policy, effective as of October 1, 2023, as it may be amended from time to time (the “Clawback Policy”), notwithstanding the foregoing, the Clawback Policy shall be applicable to this Agreement and any award or right granted hereunder.

(h)Detrimental Activity

Notwithstanding anything to the contrary contained herein, if a Participant has engaged in any Detrimental Activity, as determined by the Committee, the Committee may, in its sole discretion, provide for one or more of the following: (i) cancellation of any or all of such Participant’s outstanding Awards; or (ii) forfeiture by the Participant of any gain realized on the vesting of the Award, and repayment of any such gain promptly to the Company. For purposes of this Agreement “Detrimental Activity” means any of the following: (i) unauthorized disclosure of any confidential or proprietary information of the Company or any Subsidiary; (ii) any activity that would be grounds to terminate the Participant’s employment with the Company or any Subsidiary for Cause; (iii) the Participant having engaged in a violation of any provisions of any agreement with the Company or a Subsidiary, containing covenants regarding non-competition, non-solicitation, non-disparagement and/or non-disclosure obligations; or (iv) fraud or conduct contributing to any financial restatements or irregularities, as determined by the Committee in its sole discretion.

(i) Certain Terminations of Employment: Walk Right

Notwithstanding anything herein to the contrary, if (i) the Participant has a Termination of Service without Cause, for Good Reason, due to death or Disability, in each case at any time from the Closing and prior to or on the 24-month anniversary of the Closing; (ii) on or prior to April 10, 2025, the Company or a Subsidiary, as applicable, delivers a notice of non-renewal of the Participant’s employment agreement to the Participant; or (iii) the Participant resigns for

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any reason during the 30 day period following the 24-month anniversary of the Closing, a Final Award equal to one hundred percent (100%) of the Target Award shall be paid to the Participant in accordance with Section 3. For purposes of this Section 8(h) “Closing” shall mean the Closing of the transaction in which Vivint Smart Home, Inc. became a wholly owned Subsidiary of the Company on March 10, 2023 (the “Merger”).

9. Definition of Cause

For purposes of this Agreement “Cause”, unless otherwise defined in a Participant’s written employment arrangement with the Company or any of its Subsidiaries in effect on the date of grant (as amended from time to time thereafter), means the occurrence of one or more of the following events: (i) conviction of, or agreement to a plea of nolo contendere to, a felony, or any crime or offense lesser than a felony involving the property of the Company or a Subsidiary; (ii) conduct that has caused demonstrable and serious injury to the Company or a Subsidiary, monetary or otherwise; (iii) willful refusal to perform or substantial disregard of duties properly assigned, as determined by the Company; (iv) breach of duty of loyalty to the Company or a Subsidiary or other act of fraud or dishonesty with respect to the Company or a Subsidiary; or (v) violation of the Company’s code of conduct.

10.Committee Authority

Any question concerning the interpretation of this Agreement, any adjustments required to be made under the Plan, and any controversy that may arise under the Plan or the Grant Agreement shall be determined by the Committee in its sole discretion. Any decisions by the Committee regarding the Plan or this Agreement shall be final and binding.

11. Plan Controls

The terms of this Agreement are governed by the terms of the Plan, as it exists on the Date of the Grant and as the Plan may be amended from time to time thereafter. In the event of any conflict between the provisions of this Agreement and the provisions of the Plan, the terms of the Plan shall control.

12. Limitation on Rights; No Right to Future Grants

By entering into this Agreement, the Participant acknowledges that: (a) the Plan is discretionary and may be modified, suspended or terminated by the Company at any time, as provided in the Plan; provided that, except as provided in Section 12 of the Plan, no amendment to this Agreement shall adversely affect in a material manner the Participant’s rights hereunder without his or her written consent; (b) the grant of any award hereunder is a one-time benefit and does not create any contractual or other right to receive future grants of awards or benefits in lieu of awards; (c) all determinations with respect to any such future grants, including, but not limited to, the times when awards will be granted, the number of shares subject to each award, the award price, if any, and the time or times when each award will be settled, will be at the sole discretion of the Company; (d) participation in the Plan is voluntary; (e) the value of an award is an extraordinary item that is outside the scope of the Participant’s employment contract, if any, unless expressly provided for in any such employment contract; (f) an award is not part of normal or expected compensation for any purpose, including without limitation for calculating any benefits, severance, resignation, termination, redundancy, end of service payments, bonuses, long-service awards, pension or retirement benefits or similar payments, and the Participant will have no entitlement to compensation or damages as a consequence of any forfeiture pursuant to Section 8; (g) the future value of the Common Stock subject to the award is unknown and cannot be predicted with certainty, (h) neither the Plan, the award nor the issuance of the shares underlying the award confers upon the Participant any right to continue in the employ or service of (or any other relationship with) the Company or any Subsidiary, nor do they limit in any respect the right of the Company or any Subsidiary to terminate the Participant’s employment or other relationship with the Company or any Subsidiary, as the case may be, at any time with or without Cause, and (i) the grant of the award will not be interpreted to form an employment relationship or contract with the Company or any Subsidiary.

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13. General Provisions

(a)Notice

Whenever any notice is required or permitted hereunder, such notice must be in writing and delivered in person or by mail (to the address set forth below if notice is being delivered to the Company) or electronically. Any notice delivered in person or by mail shall be deemed to be delivered on the date on which it is personally delivered, or, whether actually received or not, on the third business day after it is deposited in the United States mail, certified or registered, postage prepaid, addressed to the person who is to receive it at the address set forth in this Agreement. Any notices delivered electronically shall be deemed to be delivered when transmitted and receipt is confirmed. Notices delivered to the Participant in person or by mail shall be addressed to the address for the Participant in the records of the Company. Notices delivered to the Company in person or by mail shall be addressed as follows:

Company: NRG Energy, Inc.
Attn: Talent
804 Carnegie Center
Princeton, NJ 08450

The Company or the Participant may change, by written notice to the other, the address previously specified for receiving notices.

(b)No Waiver

No waiver of any provision of this Agreement will be valid unless in writing and signed by the person against whom such waiver is sought to be enforced, nor will failure to enforce any right under this Agreement constitute a continuing waiver of the same or a waiver of any other right hereunder.

(c)Undertaking

The Participant hereby agrees to take whatever additional action, and execute whatever additional documents, the Company may deem necessary or advisable in order to carry out or effect one or more of the obligations or restrictions imposed on either the Participant or the award pursuant to the express provisions of this Agreement.

(d)Entire Contract

This Agreement and the Plan constitute the entire contract between the parties hereto with regard to the subject matter hereof. This Agreement is made pursuant to the provisions of the Plan and will in all respects be construed in conformity with the express terms and provisions of the Plan.

(e)Successors and Assigns

The provisions of this Agreement shall inure to the benefit of, and be binding on, the Company and its successors and assigns and Participant and Participant's legal representatives, heirs, legatees, distributees, assigns and transferees by operation of law.

(f)Securities Law Compliance

The Company currently has an effective registration statement on file with the Securities and Exchange Commission with respect to the shares of Common Stock underlying the RPSUs awarded under this Agreement. The Company intends to maintain this registration statement but has no obligation to the Participant to do so. If the registration statement ceases to be effective, the Participant will not be able to transfer or sell shares of Common Stock issued pursuant to the award, unless exemptions from registration under applicable securities laws are available. Such exemptions from registration are very limited and might be unavailable. Participant agrees that any resale of the shares of Common Stock issued pursuant to the award shall comply in all respects with the requirements of all applicable securities laws, rules and regulations (including, without limitation, the provisions of the Securities Act of 1933, the

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Securities Exchange Act of 1934 and the respective rules and regulations promulgated thereunder) and any other law, rule or regulation applicable thereto, as such laws, rules, and regulations may be amended from time to time. The Company shall not be obligated to either issue shares of Common Stock or permit the resale of any such shares if such issuance or resale would violate any such requirements.

(g)Taxes

The Participant acknowledges that the vesting and earning of RPSUs will give rise to a withholding tax liability and that no shares of Common Stock are issuable hereunder until such withholding obligation is satisfied in full. The Participant agrees to remit to the Company the amount of any taxes required to be withheld. The Committee has specifically authorized the Participant to satisfy all or part of such tax obligation by (i) withholding the number of shares of Common Stock otherwise issuable to the Participant hereunder and/or (ii) the Participant transferring to the Company unrestricted shares of Common Stock previously owned by the Participant that have a Fair Market Value equal to the amount of the withholding to be credited. Such value shall be based on the Fair Market Value of the Common Stock as of the date the amount of tax to be withheld is determined.

(h)Governing Law

Except as may otherwise be provided in the Plan, the provisions of this Agreement shall be governed by the laws of the State of Delaware without giving effect to principles of conflicts of law.

(i)Code Section 409A Compliance

To the extent that the Committee determines that the award granted under this Agreement is subject to Section 409A of the Code and fails to comply with the requirements of such Section, notwithstanding anything to the contrary contained in the Plan or in this Agreement, the Committee reserves the right to amend, restructure, terminate or replace this award in order to cause the award to either not be subject to Section 409A of the Code or comply with the applicable provisions of such Section, provided that the Participant’s consent is required if the Committee’s action would materially adversely affect the Participant.

[Signature Page Follows]

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IN WITNESS WHEREOF, this Agreement has been executed as of the Date of Grant.

NRG ENERGY, INC.

/s/ Lawrence Coben

Name:	Lawrence Coben
Title:	Interim President & CEO

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EXHIBIT A

RELATIVE TOTAL SHAREHOLDER RETURN PEER GROUP MEMBERS

The companies that make up the Standard & Poors 500 Index on the first day of the Performance Period modified in accordance with the provisions of Section 2(b) of this Agreement.

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2024 Vivint RPSU Agreement (EVP)        

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EX-10.30

Exhibit 10.30

VIVINT SMART HOME, INC. LONG-TERM INCENTIVE PLAN NOTICE OF RESTRICTED STOCK UNIT GRANT

/$ParticipantName$/

/$ParticipantAddress$/

Congratulations on your selection as a Participant under the Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan (the “Plan”). You have been chosen to receive Restricted Stock Units (“RSUs”) under the Plan. This Notice of Restricted Stock Unit Grant (the “Grant Notice”) and the attached Restricted Stock Unit Agreement (collectively referred to as the “Agreement”) constitute an agreement between you and NRG Energy, Inc. (the “Company”) pursuant to Section 9 of the Plan. In the event of any inconsistency between the terms of this Agreement and the terms of the Plan, the Plan’s terms shall supersede and replace the conflicting terms of this Agreement. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan. You are sometimes referred to as the “Participant” in this Agreement.

/$ParticipantName$/ is hereby granted RSUs as follows:

Date of Grant:	/$GrantDate$/
Vesting Commencement Date:	Date of Grant
Vesting Period:	Please refer to Section 2 of this Agreement
Total Number of RSUs:	/$AwardsGranted$/

Subject to Section 8 of this Agreement, if you do not remain an employee of the Company at all times during the Vesting Period, this Award shall terminate, and you will not be entitled to any NRG Energy, Inc. Common Stock underlying the RSUs or any dividend equivalents that may have accrued with respect thereto.

If you disagree with any of the terms of this Award or choose not to accept this Award, please contact Peter Johnson at 609-524-4759within 45 days of the Date of Grant. Otherwise, you will be deemed to have accepted this Award under the terms and conditions set forth in this Agreement and the Plan.

LEGAL\61899786\10

This Restricted Stock Unit Agreement (this “Agreement”), dated as of the Grant Date set forth in the Notice of Restricted Stock Unit Grant (the “Grant Notice,” and together with this Restricted Stock Unit Agreement, the “Agreement”) to which this Agreement is attached, is made between NRG Energy, Inc. (the “Company”) and the Participant, as set forth in the Grant Notice. The Grant Notice is included in, and made part of, this Agreement.

1.Grant of RSUs

Subject to the provisions of this Agreement and the provisions of the Vivint Smart Home, Inc. 2020 Omnibus Incentive Plan (the “Plan”), the Company hereby grants to the Participant the number of Restricted Stock Units (“RSUs”) set forth in the Grant Notice.

2.Vesting Schedule

Provided that you have been continuously employed by the Company during the vesting period, the RSUs will vest one-third each year beginning on the first anniversary of the Date of Grant. For the avoidance of doubt, the vesting period for the second and third portions of the RSUs begins when the previous one-third portion of the RSUs has completed vesting.

3.Conversion of RSUs and Issuance of Shares

As soon as reasonably practicable following vesting of the RSUs, subject to satisfaction of applicable tax withholding obligations in accordance with Section 12(g), the Company shall cause to be paid to the Participant one (1) share of NRG Energy, Inc. Common Stock for each RSU that vests on such vesting date, provided, however, that if the Participant incurs a Termination of Service that qualifies for vesting as described in Section 8, then such payment shall be made on the next administratively feasible regularly scheduled payroll date but at no time more than sixty (60) days after the vesting date described in the applicable subsection of Section 8, and, in accordance with Section 12(g), the Fair Market Value of the RSUs shall be determined as of such vesting date, less applicable taxes.

Notwithstanding the foregoing provisions of this Section 3 to the contrary, if at the time of the Participant’s separation from service within the meaning of Code Section 409A, the Participant is a “specified employee” within the meaning of Code Section 409A, any payment hereunder that constitutes a “deferral of compensation” under Code Section 409A and that would otherwise become due on account of such separation from service, shall be delayed, and payment shall be made in full upon the earlier of (a) a date during the thirty-day period commencing six (6) months and one (1) day following such separation from service and (b) the date of the Participant’s death.

4.Dividend Equivalent Rights

Cash dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to each RSU granted to the Participant; provided that such cash dividends shall be deemed to be reinvested in shares of Common Stock immediately following the time declared at the then Fair Market Value of the Common Stock and shall vest and be paid at the same time that the shares of Common Stock underlying the RSUs vest and are delivered to the Participant in accordance with the provisions hereof. Stock dividends on shares of Common Stock issuable hereunder shall be credited to a dividend book entry account on behalf of the Participant with respect to each RSU granted to the Participant; provided that such stock dividends shall vest and be paid at the same time that the shares of Common Stock underlying the RSUs vest and are delivered to the Participant in accordance with the provisions hereof. Notwithstanding the foregoing, in the event that there are insufficient shares of Common Stock available in the Plan to settle the accrued dividends in shares of Common Stock, such shares of Common Stock shall be settled in cash in an amount equal to the Fair Market Value of such shares of Common Stock at the time of settlement. Except as otherwise provided herein, the Participant shall have no rights as a stockholder with respect to any shares of Common Stock underlying any RSU unless and until the Participant has become the holder of record of such shares.

5.Transfer of RSUs

Unless otherwise permitted by the Committee or Section 13 of the Plan, the RSUs may not be sold, transferred, pledged, assigned or otherwise alienated or hypothecated, other than

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pursuant to a will or the laws of descent and distribution. Any attempted disposition in violation of this Section 5 and Section 13 of the Plan shall be void.

6.Status of Participant

The Participant shall not be, and, except as otherwise provided herein, shall not have rights as, a stockholder of the Company with respect to any of the shares of Common Stock subject to this Award, unless the Award has vested and shares of Common Stock underlying the RSUs have been issued and delivered to the Participant. The Company shall not be required to issue or transfer any certificates for shares of Common Stock upon vesting of the Award until all applicable requirements of law have been complied with and such shares have been duly listed on any securities exchange on which the Common Stock may then be listed.

7.No Effect on Capital Structure

This Award shall not affect the right of the Company or any Subsidiary to reclassify, recapitalize or otherwise change its capital or debt structure or to merge, consolidate, convey any or all of its assets, dissolve, liquidate, windup, or otherwise reorganize.

8.Expiration and Forfeiture of Award

This Award shall vest and/or expire in the circumstances described in this Section 8. As used herein, “Termination of Service” means termination of a Participant’s employment by, or service to, the Company, including any of its Subsidiaries.

(a)Death

Upon a Termination of Service by reason of death, the Award shall vest in full and the Common Stock underlying the RSUs shall be issued and delivered to the Participant's legal representatives, heirs, legatees, or distributees in accordance with Section 3.

(b)Retirement

Retirement means (i) for any non-director, unless otherwise determined by the Committee, means (A) termination of service as a non-director after at least 10 years of service by such non-director and (B) attaining at least 55 years of age, and (ii) for any director, unless otherwise determined by the Committee, means termination of service as a director after at least five years of Board service by such director.

Upon a Termination of Service in the event of Retirement, the Award shall continue to vest according to the vesting schedule; provided that Retirement occurs more than twelve (12) months following the Date of Grant. Upon vesting, the shares of Common Stock underlying the RSUs shall be issued and delivered to the Participant in accordance with Section 3.

(c)Disability

Upon a Termination of Service as a result of Disability, the Award shall vest in full, and the Common Stock underlying the RSUs shall be issued and delivered to the Participant in accordance with Section 3. For purposes of this Agreement, “Disability” means a disability that would entitle an eligible Participant to payment of monthly disability payments under any Company long-term disability plan or as otherwise determined by the Committee.

(d)Change in Control

Notwithstanding anything in this Section 8 to the contrary, if the Company terminates the Participant’s employment without Cause in connection with a Change in Control (other than the Merger, as hereinafter defined), the RSUs shall vest in full immediately upon the later of such Change in Control or such termination of employment.  Upon vesting, the Common Stock underlying the RSUs shall be issued and delivered to the Participant in accordance with Section 3. The Company’s termination of the Participant’s employment may be treated as being in connection with a Change in Control only if such termination occurs during the period beginning six (6) months prior to the Change in Control and ending twenty-four (24) months following the Change in Control. The Committee shall determine, in its sole and absolute discretion, whether the Participant’s employment was terminated without Cause in connection with a Change in Control.

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(e)Eligible Termination

Upon a Termination of Service by reason of an Eligible Termination (as defined below), the number of RSUs that shall vest and be delivered to the Participant shall be the pro-rated percentage of the total number of RSUs awarded that is equal to the percentage of time during the aggregate vesting period for all RSUs awarded that the Participant was actually continuously employed by the Company (the “Pro-Rated Award”). The Pro-Rated Award shall vest on the fifteenth (15th) day of the month that follows the month in which the Release (as defined below) becomes irrevocable; provided, that (i) in the event the aggregate consideration and revocation period applicable to the Release spans two (2) calendar years, vesting of the Pro-Rated Award shall occur in the second calendar year; and (ii) in the event aggregate consideration and revocation period applicable tothe Release ends in December, the Pro-Rated Award shall vest on December 31. Upon vesting, the Pro-Rated Award shall be issued and delivered to the Participant in accordance with Section 3.

For purposes of this Section 8(e), “Eligible Termination” means an involuntary Termination of Service in connection with the sale of a business segment, restructuring or reduction in workforce. In order to be deemed an Eligible Termination, the Participant must execute and not revoke a general release of claims in favor of the Company in a form and with terms and conditions drafted by and acceptable to the Company, which is executed, and not revoked, by the Participant as a condition to receiving the benefit described herein (the “Release”). For the avoidance of doubt: (i) an involuntary Termination of Service by reason of a Change in Control, Cause, death, or Disability is not an Eligible Termination and (ii) in the event an Eligible Termination occurs and the Award also meets the requirements for Retirement, the Award shall vest in accordance with Section 8(b). The Committee shall determine, in its sole and absolute discretion, whether a Termination of Service was by reason of an Eligible Termination.

(f)Termination of Service other than as a result of Death, Retirement, Disability, or Change in Control

Except as provided in Section 8(i), any unvested portion of this Award shall expire and be forfeited by the Participant to the Company upon a Termination of Service by: (i) any reason other than death, Retirement, Disability, or without Cause in connection with a Change in Control, including, without limitation, as a result of retirement or disability that does not meet the requirements set forth in the definitions of such terms in the Plan or this Agreement; (ii) voluntary resignation; or (iii) termination for Cause.

(g)Clawback/Repayment

All RSUs shall be subject to reduction, cancellation, forfeiture, or recoupment to the extent necessary to comply with (i) any clawback, forfeiture, or other similar policy adopted by the Board or the Committee and is in effect from time to time and (ii) applicable law. Further, unless otherwise determined by the Committee, to the extent that the Participant receives any amount in excess of the amount that the Participant should otherwise have received under the terms of the Award for any reason (including, without limitation, by reason of a financial restatement, mistake in calculations or other administrative error), the Participant shall be required to repay any such excess amount to the Company.

(h) Detrimental Activity

Notwithstanding anything to the contrary contained herein, if a Participant has engaged in any Detrimental Activity, as determined by the Committee, the Committee may, in its sole discretion, provide for one or more of the following: (i) cancellation of any or all of such Participant’s outstanding Awards; or (ii) forfeiture by the Participant of any gain realized on the vesting of the Award, and repayment of any such gain promptly to the Company. For purposes of this Agreement “Detrimental Activity” means any of the following: (i) unauthorized disclosure of any confidential or proprietary information of the Company or any Subsidiary; (ii) any activity that would be grounds to terminate the Participant’s employment with the Company or any Subsidiary for Cause; (iii) the Participant having engaged in a violation of any provisions of any agreement with the Company or a Subsidiary, containing covenants regarding non-competition, non-solicitation, non-disparagement and/or non-disclosure obligations; or (iv) fraud or conduct contributing to any financial restatements or irregularities, as determined by the Committee in its sole discretion.

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(i)Definition of Cause

For purposes of this Agreement “Cause”, unless otherwise defined in a Participant’s written employment arrangement with the Company or any of its Subsidiaries in effect on the date of grant (as amended from time to time thereafter), means the occurrence of one or more of the following events: (i) conviction of, or agreement to a plea of nolo contendere to, a felony, or any crime or offense lesser than a felony involving the property of the Company or a Subsidiary; (ii) conduct that has caused demonstrable and serious injury to the Company or a Subsidiary, monetary or otherwise; (iii) willful refusal to perform or substantial disregard of duties properly assigned, as determined by the Company; (iv) breach of duty of loyalty to the Company or a Subsidiary or other act of fraud or dishonesty with respect to the Company or a Subsidiary; or (v) violation of the Company’s code of conduct.

(j)Certain Terminations of Employment: Walk Right

Notwithstanding anything herein to the contrary, if (i) the Participant has a Termination of Service without Cause, for Good Reason, due to death or Disability, in each case at any time from the Closing and prior to or on the 24-month anniversary of the Closing; (ii) on or prior to April 10, 2025, the Company or a Subsidiary, as applicable, delivers a notice of non-renewal of the Participant’s employment agreement to the Participant; or (iii) the Participant resigns for any reason during the 30 day period following the 24-month anniversary of the Closing, the RSUs shall vest in full immediately upon the occurrence of any of the events described in subclauses (i), (ii) or (iii).   Upon vesting, the Shares underlying the RSUs shall be issued and delivered to the Participant in accordance with Section 3. For purposes of this Section 8(i) “Closing” shall mean the Closing of the transaction in which Vivint Smart Home, Inc. became a wholly owned Subsidiary of the Company on March 10, 2023 (the “Merger”).

9.Committee Authority

Any question concerning the interpretation of this Agreement, any adjustments required to be made under the Plan, and any controversy that may arise under the Plan or this Agreement shall be determined by the Committee in its sole discretion. Any decisions by the Committee regarding the Plan or this Agreement shall be final and binding.

10. Plan Controls

The terms of this Agreement are governed by the terms of the Plan, as it exists on the Date of Grant and as the Plan may be amended from time to time thereafter. In the event of any conflict between the provisions of this Agreement and the provisions of the Plan, the terms of the Plan shall control. Capitalized terms used but not defined in this Agreement shall have the meaning assigned to them in the Plan.

11. Limitation on Rights; No Right to Future Grants

By entering into this Agreement and accepting this Award, the Participant acknowledges that: (i)) the Plan is discretionary and may be modified, suspended or terminated by the Company at any time, as provided in the Plan; provided that, except as provided in Section 12 of the Plan, no amendment to this Agreement shall adversely affect in a material manner the Participant’s rights under this Agreement without his or her written consent; (ii) the grant of this Award is a one-time benefit and does not create any contractual or other right to receive future grants of awards or benefits in lieu of awards; (iii) all determinations with respect to any such future grants, including, but not limited to, the times when awards will be granted, the number of shares subject to each award, the award price, if any, and the time or times when each award will be settled, will be at the sole discretion of the Company; (iv) participation in the Plan is voluntary; (v) the value of this Award is an extraordinary item that is outside the scope of the Participant's employment contract, if any, unless expressly provided for in any such employment contract; (vi) this Award is not part of normal or expected compensation for any purpose, including, without limitation, for calculating any benefits, severance, resignation, termination, redundancy, end of service payments, bonuses, long-service awards, pension or retirement benefits or similar payments, and the Participant will have no entitlement to compensation or damages as a consequence of any forfeiture of any portion of this Award pursuant to Section 8; (vii) the future value of the Common Stock subject to this Award is unknown and cannot be predicted with certainty, (viii) neither the Plan, this Award nor the issuance of the shares of Common Stock underlying this Award confers upon the Participant any right to continue in the employ or service of (or any other relationship with) the Company or any Subsidiary, nor do they limit in any respect the right of the Company or any Subsidiary to

5

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terminate the Participant’s employment or other relationship with the Company or any Subsidiary, as the case may be, at any time with or without Cause, and (ix) the grant of this Award will not be interpreted to form an employment relationship or contract with the Company or any Subsidiary.

12. General Provisions

(a) Notice

Company:        NRG Energy, Inc.

            Attn: Talent

            804 Carnegie Center

            Princeton, NJ 08450

Whenever any notice is required or permitted hereunder, such notice must be in writing and delivered in person or by mail (to the address set forth below if notice is being delivered to the Company) or electronically. Any notice delivered in person or by mail shall be deemed to be delivered on the date on which it is personally delivered, or, whether actually received or not, on the third business day after it is deposited in the United States mail, certified or registered, postage prepaid, addressed to the person who is to receive it at the address set forth in this Agreement. Any notice delivered electronically shall be deemed to be delivered when transmitted and receipt is confirmed. Notices delivered to the Participant in person or by mail shall be addressed to the address for the Participant in the records of the Company. Notices delivered to the Company in person or by mail shall be addressed as follows:

Company:        NRG Energy, Inc.

            Attn: Talent

            804 Carnegie Center

            Princeton, NJ 08450

The Company or the Participant may change, by written notice to the other, the address previously specified for receiving notices.

(b) No Waiver

No waiver of any provision of this Agreement will be valid unless in writing and signed by the person against whom such waiver is sought to be enforced, nor will failure to enforce any right under this Agreement constitute a continuing waiver of the same or a waiver of any other right hereunder.

(c)Undertaking

The Participant hereby agrees to take whatever additional action, and execute whatever additional documents, the Company may deem necessary or advisable in order to carry out or effect one or more of the obligations or restrictions imposed on either the Participant or the Award pursuant to the express provisions of this Agreement.

(d) Entire Contract

This Agreement and the Plan constitute the entire contract between the parties hereto with regard to the subject matter hereof. This Agreement is made pursuant to the provisions of the Plan and will, in all respects, be construed in conformity with the express terms and provisions of the Plan.

(e) Successors and Assigns

The provisions of this Agreement shall inure to the benefit of, and be binding on, the Company and its successors and assigns and Participant and Participant's legal representatives, heirs, legatees, distributees, assigns and transferees by operation of law.

(f)Securities Law Compliance

The Company currently has an effective registration statement on file with the Securities and Exchange Commission with respect to the shares of Common Stock underlying this Award. The

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Company intends to maintain this registration statement but has no obligation to the Participant to do so. If the registration statement ceases to be effective, the Participant will not be able to transfer or sell shares of Common Stock issued pursuant to this Award, unless exemptions from registration under applicable securities laws are available. Such exemptions from registration are very limited and might be unavailable. Participant agrees that any resale of the shares of Common Stock issued pursuant to this Award shall comply in all respects with the requirements of all applicable securities laws, rules and regulations (including, without limitation, the provisions of the Securities Act of 1933, the Securities Exchange Act of 1934 and the respective rules and regulations promulgated thereunder) and any other law, rule or regulation applicable thereto, as such laws, rules, and regulations may be amended from time to time. The Company shall not be obligated to either issue shares of Common Stock or permit the resale of any such shares if such issuance or resale would violate any such requirements.

(g) Taxes

The Participant acknowledges that the vesting and earning of the RSUs will give rise to a withholding tax liability and that no shares of Common Stock are issuable hereunder until such withholding obligation is satisfied in full. The Participant agrees to remit to the Company the amount of any taxes required to be withheld. The Committee has specifically authorized the Participant to satisfy all or part of such tax obligation by (i) withholding the number of shares of Common Stock otherwise issuable to the Participant hereunder and/or (ii) the Participant transferring to the Company unrestricted shares of Common Stock previously owned by the Participant that have a Fair Market Value equal to the amount of the withholding to be credited. Such value shall be based on the Fair Market Value of the Common Stock as of the date the amount of tax to be withheld is determined.

(h) Governing Law

Except as may otherwise be provided in the Plan, the provisions of this Agreement shall be governed by the laws of the State of Delaware without giving effect to principles of conflicts of law.

(i)Code Section 409A Compliance

To the extent that the Committee determines that the Award granted under this Agreement is subject to Section 409A of the Code and fails to comply with the requirements of such Section, notwithstanding anything to the contrary contained in the Plan or in this Agreement, the Committee reserves the right to amend, restructure, terminate or replace this Award in order to cause the Award to either not be subject to Section 409A of the Code or comply with the applicable provisions of such Section, provided that the Participant’s consent is required if the Committee’s action would materially adversely affect the Participant.

[Signature Page Follows]

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IN WITNESS WHEREOF, this Agreement has been executed as of the Date of Grant.

NRG ENERGY, INC.

/s/ Lawrence Coben

Name:	Lawrence Coben
Title:	Interim President & CEO

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EX-21.1

EXHIBIT 21.1

SUBSIDIARIES OF NRG ENERGY, INC.

ENTITY NAME	JURISDICTION
313 Aviation, LLC	Utah
3279405 Nova Scotia Company	Nova Scotia
3283764 Nova Scotia Company	Nova Scotia
7549709 Canada Inc.	Ontario
7644868 Canada Inc.	Ontario
7711565 Canada Inc.	Ontario
Ace Energy, Inc.	New York
Airtron, Inc.	Delaware
Allied Home Warranty GP LLC	Delaware
Allied Warranty LLC	Texas
AP AL LLC	Delaware
APX Group Holdings, Inc.	Delaware
APX Group, Inc.	Delaware
Astoria Gas Turbine Power LLC	Delaware
Astoria Holdings LLC	Delaware
AWHR America's Water Heater Rentals, L.L.C.	Delaware
Beheer-en Beleggingsmaatschappij Plogema B.V.	Netherlands
Berrians Holdings LLC	Delaware
Berrians I Gas Turbine Power LLC	Delaware
Bluewater Wind Delaware LLC	Delaware
Bounce Energy, Inc.	Delaware
Cabrillo Power I LLC	Delaware
Cabrillo Power II LLC	Delaware
Camino Energy, LLC	California
Carbon Management Solutions LLC	Delaware
Cedar Bayou 5 Holdings LLC	Delaware
Choose Who You Use, Inc.	Pennsylvania
Cirro Energy Services, Inc.	Texas
Cirro Group, Inc.	Texas
Citizens Power Holdings One, LLC	Delaware
CPL Retail Energy L.P.	Delaware
Delaware Power Development LLC	Delaware
Direct Energy (B.C.) Limited	British Columbia
Direct Energy Business, LLC	Delaware
Direct Energy Connected Home Canada Inc.	Alberta
Direct Energy Connected Home US Inc.	Delaware
Direct Energy GP, LLC	Delaware
Direct Energy HoldCo GP LLC	Delaware
Direct Energy Holdings (Alberta) Inc.	Alberta

Direct Energy Leasing, LLC	Delaware
Direct Energy Marketing Inc.	Delaware
Direct Energy Marketing Limited	Ontario
Direct Energy Operations, LLC	Delaware
Direct Energy Partnership	Alberta
Direct Energy Services, LLC	Delaware
Direct Energy US Holdings Inc.	Delaware
Direct Energy, LP	Texas
Doga Enerji Uretim Sanayi ve Ticaret Limited Sirketi	Turkey
Doga Isi Satis Hizmetleri Ticaret Limited Sirketi	Turkey
Doga Isletme ve Bakim Ticaret Limited Sirketi	Turkey
Dunkirk Gas Corporation	New York
Dunkirk Power LLC	Delaware
Eastern Sierra Energy Company LLC	California
Ecokap Power LLC	Delaware
El Segundo Energy Center II LLC	Delaware
El Segundo Power II LLC	Delaware
El Segundo Power, LLC	Delaware
EME Eastern Holdings, LLC	Delaware
Energy Alternatives Wholesale, LLC	Delaware
Energy Choice Solutions LLC	Texas
Energy Plus Holdings LLC	Delaware
Energy Plus Natural Gas LLC	Delaware
Energy Protection Insurance Company	Vermont
Everything Energy LLC	Delaware
Farmington IP LLC	Delaware
First Choice Power, LLC	Texas
Forward Home Security, LLC	Texas
Gateway Energy Services Corporation	New York
GCP Funding Company, LLC	Delaware
Gladstone Power Station Joint Venture	Australia
Goal Zero LLC	Delaware
Green Mountain Energy Company	Delaware
Gregory Partners, LLC	Delaware
Hedionda Energy Storage LLC	Delaware
Home Warranty Holdings Corp.	Delaware
Huntley IGCC LLC	Delaware
Huntley Power LLC	Delaware
Independence Energy Alliance LLC	Delaware
Independence Energy Group LLC	Delaware
Independence Energy Natural Gas LLC	Delaware
Indian River Operations Inc.	Delaware
Indian River Power LLC	Delaware

IPR LLC	Delaware
Ivanpah Master Holdings, LLC	Delaware
Ivanpah Project I Holdings, LLC	Delaware
Ivanpah Project II Holdings, LLC	Delaware
Ivanpah Project III Holdings, LLC	Delaware
Jewett Mine LLC	Delaware
Krystallos Energy Storage LLC	Delaware
Legacy Vivint Smart Home, Inc.	Delaware
Maplekey UK Finance Limited	United Kingdom
Maplekey UK Limited	United Kingdom
Masters, Inc.	Maryland
MEC Esenyurt B.V.	Netherlands
MEC San Pascual B.V.	Netherlands
Meriden Gas Turbines LLC	Delaware
Midway-Sunset Cogeneration Company	California
Midwest Finance Company, LLC	Delaware
Midwest Generation EME, LLC	Delaware
Midwest Generation Holdings I, LLC	Delaware
Midwest Generation Holdings II, LLC	Delaware
Midwest Generation Procurement Services, LLC	Delaware
Midwest Generation, LLC	Delaware
Midwest Peaker Holdings, LLC	Delaware
Mission Energy Holdings International, LLC	Delaware
Mission Midway-Sunset Holdings, LLC	Delaware
Mission Midwest Coal, LLC	Delaware
Mission Watson Holdings, LLC	Delaware
NEO Corporation	Minnesota
New Genco GP, LLC	Delaware
New Jersey Power Development LLC	Delaware
Norwalk Power LLC	Delaware
NRG Acquisition Holdings Inc.	Delaware
NRG Affiliate Services Inc.	Delaware
NRG Alexandria LLC	Delaware
NRG Arroyo Nogales LLC	Delaware
NRG Arthur Kill Operations Inc.	Delaware
NRG Asia-Pacific, Ltd.	Delaware
NRG Astoria Gas Turbine Operations Inc.	Delaware
NRG Astoria Investment Holdco LLC	Delaware
NRG Astoria Power LLC	Delaware
NRG Astoria Storage LLC	Delaware
NRG Berrians East Development LLC	Delaware
NRG Bluewater Holdings LLC	Delaware
NRG Bourbonnais LLC	Illinois

NRG Brazoria Energy LLC	Delaware
NRG Business Marketing LLC	Delaware
NRG Business Services LLC	Delaware
NRG Cabrillo Power Operations Inc.	Delaware
NRG California Peaker Operations LLC	Delaware
NRG Carbon 360 LLC	Delaware
NRG CB5 Holdings LLC	Delaware
NRG Cedar Bayou 5 LLC	Delaware
NRG Cedar Bayou Development Company, LLC	Delaware
NRG Chalk Point CT LLC	Delaware
NRG Coal Development Company LLC	Delaware
NRG Common Stock Finance I LLC	Delaware
NRG Common Stock Finance II LLC	Delaware
NRG Connected Home LLC	Delaware
NRG Construction LLC	Delaware
NRG Controllable Load Services LLC	Delaware
NRG Cottonwood Tenant LLC	Delaware
NRG CTA Holdings LLC	Delaware
NRG Curtailment Solutions Canada, Inc.	British Columbia
NRG Curtailment Solutions, Inc.	New York
NRG Development Company Inc.	Delaware
NRG DG Development LLC	Delaware
NRG dGen Advisory Services LLC	Delaware
NRG Dispatch Services LLC	Delaware
NRG Distributed Energy Resources Holdings LLC	Delaware
NRG Distributed Generation PR LLC	Delaware
NRG Dunkirk Operations Inc.	Delaware
NRG ECOKAP Holdings LLC	Delaware
NRG El Segundo Operations Inc.	Delaware
NRG Energy Center Eagles LLC	Delaware
NRG Energy Center Oxnard LLC	Delaware
NRG Energy Fuel Services LLC	Delaware
NRG Energy Gas & Wind Holdings, Inc.	Delaware
NRG Energy Holdings Inc.	Delaware
NRG Energy Labor Services LLC	Delaware
NRG Energy Services Group LLC	Delaware
NRG Energy Services LLC	Delaware
NRG Energy, Inc.	Delaware
NRG Equipment Company LLC	Nevada
NRG Fuel Cell CA1 LLC	Delaware
NRG Fuel Resources LLC	Delaware
NRG Fuel Transportation LLC	Delaware
NRG Gas Development Company, LLC	Delaware

NRG Generation Holdings Inc.	Delaware
NRG Gladstone Operating Services Pty Ltd	Australia
NRG Greens Bayou 6 LLC	Delaware
NRG Greens Bayou Mobile Energy Solutions LLC	Delaware
NRG GTL Holdings LLC	Delaware
NRG Home & Business Solutions LLC	Delaware
NRG Home Services LLC	Texas
NRG Home Solutions LLC	Delaware
NRG Home Solutions Product LLC	Delaware
NRG Homer City Services LLC	Delaware
NRG HQ DG LLC	Delaware
NRG Huntley Operations Inc.	Delaware
NRG Identity Protect LLC	Delaware
NRG Independence Solar LLC	Delaware
NRG Indian River Storage LLC	Delaware
NRG International LLC	Delaware
NRG Lease Co, LLC	Delaware
NRG Limestone 3, LLC	Delaware
NRG Maintenance Services LLC	Delaware
NRG Mextrans Inc.	Delaware
NRG MidCon Development LLC	Delaware
NRG Middletown Repowering LLC	Delaware
NRG Midwest Holdings LLC	Delaware
NRG Midwest Storage LLC	Delaware
NRG NE Development LLC	Delaware
NRG NewGen LLC	Delaware
NRG Norwalk Harbor Operations Inc.	Delaware
NRG Ohio Pipeline Company LLC	Delaware
NRG Operating Services, Inc.	Delaware
NRG Oxbow Holdings LLC	Delaware
NRG Portable Power LLC	Delaware
NRG Potrero Development LLC	Delaware
NRG Procurement Company LLC	Nevada
NRG Project Company LLC	Delaware
NRG Protects Inc. (CA)	California
NRG Protects Inc. (IL)	Illinois
NRG Receivables LLC	Delaware
NRG Reliability Solutions LLC	Delaware
NRG Renter's Protection LLC	Delaware
NRG Repowering Holdings LLC	Delaware
NRG Residential Solar Solutions LLC	Delaware
NRG Retail LLC	Delaware
NRG Retail Northeast LLC	Delaware

NRG Rockford Acquisition LLC	Delaware
NRG Saguaro Operations Inc.	Delaware
NRG Security LLC	Delaware
NRG Services Corporation	Delaware
NRG Sherbino LLC	Delaware
NRG SimplySmart Solutions LLC	Delaware
NRG Solar Arrowhead LLC	Delaware
NRG Solar CVSR Holdings 2 LLC	Delaware
NRG Solar Ivanpah LLC	Delaware
NRG Solar Ring LLC	Delaware
NRG Solar SC Stadium LLC	Delaware
NRG Solar Sunrise LLC	Delaware
NRG Storage Fabrication & Delivery LLC	Delaware
NRG Storage on Demand NY LLC	Delaware
NRG Texas Gregory LLC	Delaware
NRG Texas Holding Inc.	Delaware
NRG Texas LLC	Delaware
NRG Texas Power LLC	Delaware
NRG Texas Retail LLC	Delaware
NRG THW GT LLC	Delaware
NRG Trading Advisors LLC	Delaware
NRG Transmission Holdings LLC	Delaware
NRG ULC Parent, Inc.	Delaware
NRG Victoria I Pty Ltd	Australia
NRG Warranty Services LLC	Delaware
NRG Waukegan Storage LLC	Delaware
NRG West Coast LLC	Delaware
NRG Western Affiliate Services Inc.	Delaware
NRG Will County Storage LLC	Delaware
NRG Wind Development Company, LLC	Delaware
NRG Wind LLC	Delaware
NRGenerating German Holdings GmbH	Switzerland
NRGenerating International B.V.	Netherlands
NRGenerating Luxembourg (No. 1) S.a.r.l.	Luxembourg
NRGenerating Luxembourg (No. 2) S.a.r.l.	Luxembourg
Petra Nova Holdings LLC	Delaware
Pure Energies Group ULC	Nova Scotia
Pure Energies Installation Inc.	Delaware
Pure Energies Solar Services Inc.	Ontario
Pure Group, Inc.	California
RDI Consulting, LLC	Delaware
Reliant Charitable Foundation	Delaware
Reliant Energy Northeast LLC	Delaware

Reliant Energy Power Supply, LLC	Delaware
Reliant Energy Retail Holdings, LLC	Delaware
Reliant Energy Retail Services, LLC	Delaware
RERH Holdings, LLC	Delaware
Restoration Design LLC	New Jersey
Roof Diagnostics Solar and Electric LLC	New Jersey
Roof Diagnostics Solar and Electric of NY, LLC	New York
Roof Diagnostics Solar Holdings LLC	Delaware
RSG Holding Corp.	Delaware
Saguaro Power LLC	Delaware
San Joaquin Energy, LLC	California
SGE Energy Sourcing, LLC	Delaware
SGE Texas Holdco, LLC	Texas
Smart Home Pros, Inc.	Utah
Solar Partners I, LLC	Delaware
Solar Partners II, LLC	Delaware
Solar Partners VIII, LLC	Delaware
Solar Pure Energies ULC	Nova Scotia
Somerset Operations Inc.	Delaware
Somerset Power LLC	Delaware
Space Monkey, LLC	Delaware
Station A LLC	Delaware
Strategic NRG Acquisition Corp.	Delaware
Strategic NRG Sponsor LLC	Delaware
Stream Energy Columbia, LLC	Delaware
Stream Energy Delaware, LLC	Delaware
Stream Energy Illinois, LLC	Delaware
Stream Energy Maryland, LLC	Delaware
Stream Energy New Jersey, LLC	Delaware
Stream Energy New York, LLC	Delaware
Stream Energy Pennsylvania, LLC	Delaware
Stream Georgia Gas SPE, LLC	Georgia
Stream Ohio Gas & Electric, LLC	Ohio
Stream SPE GP, LLC	Texas
Stream SPE, Ltd.	Texas
Sunshine State Power (No. 2) B.V.	Netherlands
Sunshine State Power B.V.	Netherlands
Tacoma Energy Recovery Company	Delaware
Texas Genco GP, LLC	Texas
Texas Genco Holdings, Inc.	Texas
Texas Genco LP, LLC	Delaware
Texas Genco Services, LP	Texas
Three+ Venture Group LLC	Delaware

US Retailers LLC	Delaware
Valle Del Sol Energy, LLC	Delaware
VI Administrative Services, LLC	Delaware
Vienna Operations Inc.	Delaware
Vienna Power LLC	Delaware
Vivint Amigo, Inc.	Delaware
Vivint Funding Holdings LLC	Delaware
Vivint Funding US LLC	Delaware
VIVINT GIVES BACK	Utah
Vivint Group, Inc.	Delaware
Vivint Insurance Services, LLC	Delaware
Vivint Louisiana LLC	Louisiana
Vivint Purchasing, LLC	Utah
Vivint Services Canada Inc.	British Columbia
Vivint Servicing LLC	Delaware
Vivint Smart Home, Inc.	Delaware
Vivint Solar Licensing, LLC	Delaware
Vivint VI Holdings, LLC	Delaware
Vivint Warranty and Home Insurance, LLC	Delaware
Vivint, Inc.	Utah
WCP (Generation) Holdings LLC	Delaware
West Coast Power LLC	Delaware
WTU Retail Energy L.P.	Delaware
XOOM Alberta Holdings, LLC	Delaware
XOOM British Columbia Holdings, LLC	Delaware
XOOM Energy BC, ULC	Nova Scotia
XOOM Energy California, LLC	California
XOOM Energy Canada, ULC	Nova Scotia
XOOM Energy Connecticut, LLC	Connecticut
XOOM Energy Delaware, LLC	Delaware
XOOM Energy Georgia, LLC	Georgia
XOOM Energy Global Holdings, LLC	Delaware
XOOM Energy Illinois LLC	Illinois
XOOM Energy Indiana, LLC	Indiana
XOOM Energy Kentucky, LLC	Kentucky
XOOM Energy Maine, LLC	Maine
XOOM Energy Maryland, LLC	Maryland
XOOM Energy Massachusetts, LLC	Massachusetts
XOOM Energy Michigan, LLC	Michigan
XOOM Energy New Hampshire, LLC	New Hampshire
XOOM Energy New Jersey, LLC	New Jersey
XOOM Energy New York, LLC	New York
XOOM Energy Ohio, LLC	Ohio

XOOM Energy ONT, ULC	Nova Scotia
XOOM Energy Pennsylvania, LLC	Pennsylvania
XOOM Energy Rhode Island, LLC	Rhode Island
XOOM Energy Texas, LLC	Texas
XOOM Energy Virginia, LLC	Virginia
XOOM Energy Washington D.C., LLC	District of Columbia
XOOM Energy, LLC	Delaware
XOOM Ontario Holdings, LLC	Delaware
XOOM Solar, LLC	Delaware

EX-22.1

EXHIBIT 22.1

LIST OF GUARANTOR SUBSIDIARIES

The following subsidiaries of NRG Energy, Inc. were guarantors of the Company'soutstanding registered senior notes of $375 million of the 2027 Senior Notes and $821 million of the 2028 Senior Notes:

ENTITY NAME	JURISDICTION
Ace Energy, Inc.	New York
Airtron, Inc.	Delaware
Allied Home Warranty GP LLC	Delaware
Allied Warranty LLC	Texas
Astoria Gas Turbine Power LLC	Delaware
AWHR America's Water Heater Rentals, L.L.C.	Delaware
Bounce Energy, Inc.	Delaware
Cabrillo Power I LLC	Delaware
Cabrillo Power II LLC	Delaware
Carbon Management Solutions LLC	Delaware
Cirro Energy Services, Inc.	Texas
Cirro Group, Inc.	Texas
CPL Retail Energy L.P.	Delaware
Direct Energy Business, LLC	Delaware
Direct Energy Connected Home US Inc.	Delaware
Direct Energy GP, LLC	Delaware
Direct Energy HoldCo GP LLC	Delaware
Direct Energy Leasing, LLC	Delaware
Direct Energy Marketing Inc.	Delaware
Direct Energy Operations, LLC	Delaware
Direct Energy Services, LLC	Delaware
Direct Energy US Holdings Inc.	Delaware
Direct Energy, LP	Texas
Dunkirk Power LLC	Delaware
Eastern Sierra Energy Company LLC	California
El Segundo Power II LLC	Delaware
El Segundo Power, LLC	Delaware
Energy Alternatives Wholesale, LLC	Delaware
Energy Choice Solutions LLC	Texas
Energy Plus Holdings LLC	Delaware
Energy Plus Natural Gas LLC	Delaware
Everything Energy LLC	Delaware
First Choice Power, LLC	Texas
Forward Home Security, LLC	Texas
Gateway Energy Services Corporation	New York
GCP Funding Company, LLC	Delaware
Green Mountain Energy Company	Delaware

Gregory Partners, LLC	Delaware
Home Warranty Holdings Corp.	Delaware
Huntley Power LLC	Delaware
Independence Energy Alliance LLC	Delaware
Independence Energy Group LLC	Delaware
Independence Energy Natural Gas LLC	Delaware
Indian River Operations Inc.	Delaware
Indian River Power LLC	Delaware
Masters, Inc.	Maryland
Meriden Gas Turbines LLC	Delaware
NEO Corporation	Minnesota
New Genco GP, LLC	Delaware
Norwalk Power LLC	Delaware
NRG Affiliate Services Inc.	Delaware
NRG Arthur Kill Operations Inc.	Delaware
NRG Astoria Gas Turbine Operations Inc.	Delaware
NRG Business Marketing LLC	Delaware
NRG Business Services LLC	Delaware
NRG Cabrillo Power Operations Inc.	Delaware
NRG California Peaker Operations LLC	Delaware
NRG Cedar Bayou Development Company, LLC	Delaware
NRG Connected Home LLC	Delaware
NRG Construction LLC	Delaware
NRG Controllable Load Services LLC	Delaware
NRG Curtailment Solutions, Inc.	New York
NRG Development Company Inc.	Delaware
NRG Dispatch Services LLC	Delaware
NRG Distributed Energy Resources Holdings LLC	Delaware
NRG Distributed Generation PR LLC	Delaware
NRG Dunkirk Operations Inc.	Delaware
NRG ECOKAP Holdings LLC	Delaware
NRG El Segundo Operations Inc.	Delaware
NRG Energy Labor Services LLC	Delaware
NRG Energy Services Group LLC	Delaware
NRG Energy Services LLC	Delaware
NRG Generation Holdings Inc.	Delaware
NRG Home & Business Solutions LLC	Delaware
NRG Home Services LLC	Texas
NRG Home Solutions LLC	Delaware
NRG Home Solutions Product LLC	Delaware
NRG Homer City Services LLC	Delaware
NRG HQ DG LLC	Delaware
NRG Huntley Operations Inc.	Delaware

NRG Identity Protect LLC	Delaware
NRG International LLC	Delaware
NRG Maintenance Services LLC	Delaware
NRG Mextrans Inc.	Delaware
NRG Norwalk Harbor Operations Inc.	Delaware
NRG Operating Services, Inc.	Delaware
NRG Portable Power LLC	Delaware
NRG Protects Inc. (IL)	Illinois
NRG Reliability Solutions LLC	Delaware
NRG Renter's Protection LLC	Delaware
NRG Retail LLC	Delaware
NRG Retail Northeast LLC	Delaware
NRG Rockford Acquisition LLC	Delaware
NRG Saguaro Operations Inc.	Delaware
NRG Security LLC	Delaware
NRG Services Corporation	Delaware
NRG SimplySmart Solutions LLC	Delaware
NRG Texas Gregory LLC	Delaware
NRG Texas Holding Inc.	Delaware
NRG Texas LLC	Delaware
NRG Texas Power LLC	Delaware
NRG Warranty Services LLC	Delaware
NRG West Coast LLC	Delaware
NRG Western Affiliate Services Inc.	Delaware
Reliant Energy Northeast LLC	Delaware
Reliant Energy Power Supply, LLC	Delaware
Reliant Energy Retail Holdings, LLC	Delaware
Reliant Energy Retail Services, LLC	Delaware
RERH Holdings, LLC	Delaware
RSG Holding Corp.	Delaware
Saguaro Power LLC	Delaware
SGE Energy Sourcing, LLC	Delaware
SGE Texas Holdco, LLC	Texas
Somerset Operations Inc.	Delaware
Somerset Power LLC	Delaware
Stream Energy Columbia, LLC	Delaware
Stream Energy Delaware, LLC	Delaware
Stream Energy Illinois, LLC	Delaware
Stream Energy Maryland, LLC	Delaware
Stream Energy New Jersey, LLC	Delaware
Stream Energy New York, LLC	Delaware
Stream Energy Pennsylvania, LLC	Delaware
Stream Georgia Gas SPE, LLC	Georgia

Stream Ohio Gas & Electric, LLC	Ohio
Stream SPE GP, LLC	Texas
Stream SPE, Ltd.	Texas
Texas Genco GP, LLC	Texas
Texas Genco Holdings, Inc.	Texas
Texas Genco LP, LLC	Delaware
Texas Genco Services, LP	Texas
US Retailers LLC	Delaware
Vienna Operations Inc.	Delaware
Vienna Power LLC	Delaware
WCP (Generation) Holdings LLC	Delaware
West Coast Power LLC	Delaware
WTU Retail Energy L.P.	Delaware
XOOM Alberta Holdings, LLC	Delaware
XOOM British Columbia Holdings, LLC	Delaware
XOOM Energy California, LLC	California
XOOM Energy Connecticut, LLC	Connecticut
XOOM Energy Delaware, LLC	Delaware
XOOM Energy Georgia, LLC	Georgia
XOOM Energy Global Holdings, LLC	Delaware
XOOM Energy Illinois LLC	Illinois
XOOM Energy Indiana, LLC	Indiana
XOOM Energy Kentucky, LLC	Kentucky
XOOM Energy Maine, LLC	Maine
XOOM Energy Maryland, LLC	Maryland
XOOM Energy Massachusetts, LLC	Massachusetts
XOOM Energy Michigan, LLC	Michigan
XOOM Energy New Hampshire, LLC	New Hampshire
XOOM Energy New Jersey, LLC	New Jersey
XOOM Energy New York, LLC	New York
XOOM Energy Ohio, LLC	Ohio
XOOM Energy Pennsylvania, LLC	Pennsylvania
XOOM Energy Rhode Island, LLC	Rhode Island
XOOM Energy Texas, LLC	Texas
XOOM Energy Virginia, LLC	Virginia
XOOM Energy Washington D.C., LLC	District of Columbia
XOOM Energy, LLC	Delaware
XOOM Ontario Holdings, LLC	Delaware
XOOM Solar, LLC	Delaware

EX-23.1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in the registration statements Numbers 333-217595, 333-197882, 333-185501, 333-182379, 333-171318, 333-151992, 333-135973, 333-114007, 333-270479 and 333-273810 on Form S-8 of our reports dated February 28, 2024, with respect to the consolidated financial statements of NRG Energy, Inc. and the effectiveness of internal control over financial reporting.

/s/ KPMG LLP

Philadelphia, Pennsylvania

February 28, 2024

EX-31.1

EXHIBIT 31.1

CERTIFICATION

I, Lawrence S. Coben, certify that:

1.I have reviewed this annual report on Form 10-K of NRG 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/ LAWRENCE S. COBEN

Lawrence S. Coben

Interim President and Chief Executive Officer

Date: February 28, 2024

EX-31.2

EXHIBIT 31.2

CERTIFICATION

I, Woo-Sung Chung, certify that:

1.I have reviewed this annual report on Form 10-K of NRG 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/ WOO-SUNG CHUNG

Woo-Sung Chung

 Chief Financial Officer

(Principal Financial Officer)

Date: February 28, 2024

EX-31.3

EXHIBIT 31.3

CERTIFICATION

I, G. Alfred Spencer, certify that:

1.I have reviewed this annual report on Form 10-K of NRG 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/ G. ALFRED SPENCER

Chief Accounting Officer

(Principal Accounting Officer)

Date: February 28, 2024

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 Annual Report of NRG Energy, Inc. on Form 10-K for the year ended December 31, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Form 10-K”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer's knowledge:

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

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

Date: February 28, 2024

/s/ LAWRENCE S. COBEN

Lawrence S. Coben

Interim Chief Executive Officer (Principal Executive Officer)

/s/ WOO-SUNG CHUNG

Woo-Sung Chung

 Chief Financial Officer

(Principal Financial Officer)

/s/ G. ALFRED SPENCER

G. Alfred Spencer

Chief Accounting Officer

(Principal Accounting Officer) 

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

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

EX-97

Exhibit 97

NRG ENERGY, INC.CLAWBACK POLICY

The Board of Directors (the “Board”) of NRG Energy, Inc. (the “Company”) believes that it is in the best interests of the Company and its stockholders to adopt this Clawback Policy (this “Policy”), which provides for the recovery of certain incentive-based compensation upon the occurrence of certain events, including an Accounting Restatement (as defined below). This Policy is designed to comply with, and shall be interpreted to be consistent with, Section 10D of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), Rule 10D-1 promulgated under the Exchange Act (“Rule 10D-1”) and Section 303A.14 of the New York Stock Exchange Listed Company Manual (the “Listing Standards”), each as may be hereafter amended from time to time.

1.Administration.Except as specifically set forth herein, this Policy shall be administered by the Compensation Committee of the Board or, if so designated by the Board, the Board or another committee of the Board (the Board or such committee charged with administration of this Policy, the “Administrator”). The Administrator is authorized to interpret and construe this Policy and to make all determinations necessary, appropriate or advisable for the administration of this Policy. Any determinations made by the Administrator shall be final and binding on all affected individuals and need not be uniform with respect to each individual covered by the Policy. In the administration of this Policy, the Administrator is authorized and directed to consult with the full Board or such other committees of the Board, such as the Audit Committee, as may be necessary or appropriate as to matters within the scope of such other committee’s responsibility and authority. Subject to any limitation at applicable law, the Administrator may authorize and empower any officer or employee of the Company or any authorized agent of the Company to take any and all actions necessary or appropriate to carry out the purpose and intent of this Policy (other than with respect to any recovery under this Policy involving such officer or employee).

2.Definitions.As used in this Policy, the following definitions shall apply:

·“Accounting Restatement” means an accounting restatement of the Company’s financial statements due to the Company’s material noncompliance with any financial reporting requirement under the securities laws, including any required accounting restatement to correct an error in previously issued financial statements that is material to the previously issued financial statements, or that would result in a material misstatement if the error were corrected in the current period or left uncorrected in the current period. Notwithstanding the foregoing, the following types of changes to the Company’s financial statements do not represent error corrections, and therefore would likewise not trigger application of this Policy:

oRetrospective application of a change in accounting principle;

oRetrospective revision to reportable segment information due to a change in the structure of the Company’s internal organization;

oRetrospective reclassification due to a discontinued operation;

oRetrospective application of a change in reporting entity, such as from a reorganization of entities under common control; and

oRetrospective revision for stock splits, reverse stock splits, stock dividends or other changes in capital structure.

·“Administrator” has the meaning set forth in Section 1 hereof.

·“Applicable Period” means the three completed fiscal years immediately preceding the date on which the Company is required to prepare an Accounting Restatement, as well as any transition period (that results from a change in the Company’s fiscal year) within or immediately following those three completed fiscal years (except that a transition period that comprises a period of at least nine months shall count as a completed fiscal year).

·The “date on which the Company is required to prepare an Accounting Restatement” is the earlier to occur of (a) the date the Board, an authorized committee of the Board (e.g., the Audit Committee), or the officer or officers of the Company authorized to take such action if Board action is not required concludes, or reasonably should have concluded, that the Company is required to prepare an Accounting Restatement or (b) the date a court, regulator or other legally authorized body directs the Company to prepare an Accounting Restatement, in each case regardless of if or when the restated financial statements are filed.

·“Commission” means the U.S. Securities and Exchange Commission.

·“Covered Executives” means the Company’s current and former executive officers, as determined by the Administrator in accordance with the definition of executive officer set forth in Rule 10D-1 and the Listing Standards.

·“Erroneously Awarded Compensation” has the meaning set forth in Section 5 of this Policy.

·A “Financial Reporting Measure” is any measure that is determined and presented in accordance with the accounting principles used in preparing the Company’s financial statements, and any measure that is derived wholly or in part from such measure, whether or not such Financial Reporting Measure is included in a filing with the Commission. Financial Reporting Measures, include but are not limited to, the following (and any measures derived from the

following): price of the Company’s securities listed on a securities exchange; total stockholder return (“TSR”); revenues; net income; operating income; profitability of one or more reportable segments; financial ratios (e.g., accounts receivable turnover and inventory turnover rates); earnings before interest, taxes, depreciation and amortization (“EBITDA”); funds from operations and adjusted funds from operations; liquidity measures (e.g., working capital, operating cash flow); return measures (e.g., return on invested capital, return on assets); earnings measures (e.g., earnings per share); adjusted free cash flow (before growth); credit ratio; and any of such Financial Reporting Measures relative to a peer group, where the Company’s Financial Reporting Measure is subject to an Accounting Restatement. A Financial Reporting Measure need not be presented within the Company’s financial statements or included in a filing with the Commission.

·“Incentive-Based Compensation” means any compensation that is granted, earned or vested based wholly or in part upon the attainment of a Financial Reporting Measure, including, without limitation, (i) non-equity incentive plan awards that are earned based wholly or in part on satisfying a Financial Reporting Measure performance goal; (ii) bonuses paid from a “bonus pool,” the size of which is determined based wholly or in part on satisfying a Financial Reporting Measure performance goal; (iii) other cash awards based on satisfaction of a Financial Reporting Measure performance goal; (iv) restricted stock, restricted stock units, performance share units, stock options, and stock appreciation rights that are granted or become vested based wholly or in part on satisfying a Financial Reporting Measure performance goal; and (v) proceeds received upon the sale of shares acquired through an incentive plan that were granted or vested based wholly or in part on satisfying a Financial Reporting Measure performance goal.

·Incentive-Based Compensation is “received” for purposes of this Policy in the Company’s fiscal period during which the Financial Reporting Measure specified in the Incentive-Based Compensation award is attained, even if the payment or grant of such Incentive-Based Compensation occurs after the end of that period. All conditions to an award for Incentive-Based Compensation need not be satisfied for the Incentive-Based Compensation to be deemed received under this Policy. Incentive-Based Compensation is deemed received even if there is a contingent right to payment at that time or payment remains subject to ministerial acts, such as calculating the amount earned or obtaining the approval of the Administrator or the Board.

3.Covered Executives; Incentive-Based Compensation.Except as set forth in Section 11 of this Policy, this Policy applies to Incentive-Based Compensation received by a Covered Executive (a) after beginning services as a Covered Executive; (b) if that person served as a Covered Executive at any time during the performance period for such Incentive-Based

Compensation; and (c) while the Company had a listed class of securities on a national securities exchange.

4.Required Recoupment of Erroneously Awarded Compensation in the Event of an Accounting Restatement.In the event the Company is required to prepare an Accounting Restatement, the Company shall promptly recoup the amount of any Erroneously Awarded Compensation received by any Covered Executive, as calculated pursuant to Section 5 hereof, during the Applicable Period.

5.Erroneously Awarded Compensation: Amount Subject to Recovery. The amount of “Erroneously Awarded Compensation” subject to recovery under this Policy, as determined by the Administrator, is the amount of Incentive-Based Compensation received by the Covered Executive that exceeds the amount of Incentive-Based Compensation that would have been received by the Covered Executive had it been determined based on the restated amounts.Erroneously Awarded Compensation shall be computed by the Administrator without regard to any taxes paid by the Covered Executive in respect of the Erroneously Awarded Compensation. With respect to any compensation plans or programs that take into account Incentive-Based Compensation, the amount of Erroneously Awarded Compensation subject to recovery hereunder includes, but is not limited to, the amount contributed to any notional account based on Erroneously Awarded Compensation and any earnings accrued to date on that notional amount.

For Incentive-Based Compensation based on stock price or TSR: (a) the Administrator shall determine the amount of Erroneously Awarded Compensation based on a reasonable estimate of the effect of the Accounting Restatement on the stock price or TSR upon which the Incentive-Based Compensation was received; and (b) the Company shall maintain documentation of the determination of that reasonable estimate and provide such documentation to the New York Stock Exchange (“NYSE”).

6.Method of Recoupment. The Administrator shall determine, in its sole discretion, the timing and method for promptly recouping Erroneously Awarded Compensation hereunder, as well as a reasonable amount of interest, as determined by the Administrator, to compensate the Company for the time-value of the Erroneously Awarded Compensation and reimbursement of direct expenses to recover the Erroneously Awarded Compensation, including without limitation any legal fees incurred by the Company, which may include without limitation (a) seeking reimbursement of all or part of any cash or equity-based award, (b) cancelling prior cash or equity-based awards, whether vested or unvested or paid or unpaid, (c) forfeiture of deferred compensation, subject to compliance with Section 409A of the Internal Revenue Code and the regulations promulgated thereunder and (d) any other method authorized by applicable law or contract. Subject to compliance with any applicable law, the Administrator may affect recovery under this Policy from any amount otherwise payable to the Covered Executive, including amounts payable to such individual under any otherwise applicable Company plan or program, including base salary, bonuses or commissions and compensation previously deferred by the Covered Executive.

The Company is authorized and directed pursuant to this Policy to recoup Erroneously Awarded Compensation in compliance with this Policy unless the Compensation Committee of the Board has determined that recovery would be impracticable solely for the following limited reasons, and subject to the following procedural and disclosure requirements:

·The direct expense paid to a third party to assist in enforcing the Policy would exceed the amount to be recovered. Before concluding that it would be impracticable to recover any amount of Erroneously Awarded Compensation based on expense of enforcement, the Administrator must make a reasonable attempt to recover such erroneously awarded compensation, document such reasonable attempt(s) to recover and provide that documentation to NYSE;

·Recovery would violate home country law of the Company where that law was adopted prior to November 28, 2022. Before concluding that it would be impracticable to recover any amount of Erroneously Awarded Compensation based on violation of home country law of the Company, the Administrator must satisfy the applicable opinion and disclosure requirements of Rule 10D-1 and the Listing Standards; or

·Recovery would likely cause an otherwise tax-qualified retirement plan, under which benefits are broadly available to employees of the Company, 1 to fail to meet the requirements of 26 U.S.C. 401(a)(13) or 26 U.S.C. 411(a) and regulations thereunder.

7.No Indemnification of Covered Executives. Notwithstanding the terms of any indemnification or insurance policy or any contractual arrangement with any Covered Executive that may be interpreted to the contrary, the Company shall not indemnify any Covered Executives against the loss of any Erroneously Awarded Compensation, including any payment or reimbursement for the cost of third-party insurance purchased by any Covered Executives to fund potential clawback obligations under this Policy.

8.Administrator Indemnification. Any members of the Administrator, and any other members of the Board who assist in the administration of this Policy, shall not be personally liable for any action, determination or interpretation made with respect to this Policy and shall be fully indemnified by the Company to the fullest extent under applicable law and Company policy with respect to any such action, determination or interpretation. The foregoing sentence shall not limit any other rights to indemnification of the members of the Board under applicable law or Company policy.

9.Compliance Date; Retroactive Application. The Company must comply with this Policy beginning on October 1, 2023 (the “Compliance Date”). The terms of this Policy shall apply to any Incentive-Based Compensation that is received by Covered Executives on or after

1 Plans limited only to executive officers, SERPS and other nonqualified plan, and benefits therefrom, are subject to recovery under this Policy.

the Compliance Date,even if such Incentive-Based Compensation was approved, awarded, granted or paid to Covered Executives prior to the Compliance Date. Without limiting the generality of Section 6 hereof, and subject to applicable law, the Administrator may affect recovery under this Policy from any amount of compensation approved, awarded, granted, payable or paid to the Covered Executive prior to, on or after the Compliance Date.

10.Amendment; Termination. The Board may amend, modify, supplement, rescind or replace all or any portion of this Policy at any time and from time to time in its discretion, and shall amend this Policy as it deems necessary to comply with applicable law or any rules or standards adopted by a national securities exchange on which the Company’s securities are listed. The Administrator may make such amendments or modifications to this Policy to the extent such amendments or modifications are administrative in nature and not material.

11.Other Recoupment Rights; Company Claims. The Board intends that this Policy shall be applied to the fullest extent of the law. Any right of recoupment under this Policy is in addition to, and not in lieu of, any other remedies or rights of recoupment that may be available to the Company under applicable law or pursuant to the terms of any similar policy in any employment agreement, equity award agreement, or similar agreement and any other legal remedies available to the Company.

Nothing contained in this Policy, and no recoupment or recovery as contemplated by this Policy, shall limit any claims, damages or other legal remedies the Company or any of its affiliates may have against a Covered Executive arising out of or resulting from any actions or omissions by the Covered Executive.

Notwithstanding anything set forth in this Policy, by signing the acknowledgement below, the Company’s Chief Executive Officer and Chief Financial Officer acknowledge that in the event the Company is required to prepare an accounting restatement subject to Section 304 of the Sarbanes-Oxley Act of 2002, as amended (“Section 304”), she or he shall forfeit such amounts required pursuant to Section 304.

12.Successors. This Policy shall be binding and enforceable against all Covered Executives and their beneficiaries, heirs, executors, administrators or other legal representatives.

13.Governing Law, Dispute Resolution and Venue.This Policy and all acts and transactions pursuant hereto and the rights and obligations of the Parties hereto will be governed, construed and interpreted in accordance with the laws of the State of Delaware, without giving effect to such state’s conflict of laws rules.

Any and all disputes relating to, concerning or arising from this Policy, or relating to, concerning or arising from the relationship between the parties evidenced by this Policy, will be brought and heard exclusively in the United States District Court for the State of Delaware or the applicable local court. Each of the Company and each person subject to this Policy

hereby represents and agrees that such party is subject to the personal jurisdiction of said courts; hereby irrevocably consents to the jurisdiction of such courts in any legal or equitable proceedings related to, concerning, or arising from such dispute, and waives, to the fullest extent permitted by law, any objection which such party may now or hereafter have that the laying of the venue of any legal or equitable proceedings related to, concerning, or arising from such dispute which is brought in such courts is improper or that such proceedings have been brought in an inconvenient forum.

14.Exhibit Filing Requirement. A copy of this Policy and any amendments thereto shall be posted on the Company’s website and filed as an exhibit to the Company’s annual report on Form 10-K.

15.Conflict with Policy. In the event there is a conflict between the terms of this Policy and any other policy or compensation arrangement made by the Company, the terms of this Policy shall govern.

[TO BE SIGNED BY THE COMPANY’S EXECUTIVE OFFICERS:]

Clawback Policy Acknowledgment

I, the undersigned, agree and acknowledge that, in consideration of good and valuable consideration, I am fully bound by, and subject to, all of the terms and conditions of the NRG Energy, Inc. Clawback Policy (as may be amended, restated, supplemented or otherwise modified from time to time, the “Policy”). In the event of any inconsistency between the Policy and the terms of any employment agreement to which I am a party, or the terms of any compensation plan, program or agreement, offer or similar arrangement under which any compensation has been granted, awarded, earned or paid, the terms of the Policy shall govern. In the event it is determined by the Administrator that any amounts granted, awarded, earned or paid to me must be forfeited or reimbursed to the Company, I will promptly take any action necessary to effectuate such forfeiture and/or reimbursement. Any capitalized terms used in this Acknowledgment without definition shall have the meaning set forth in the Policy.

By:         

[Name]    Date

[Title]

XML

Cover - USD ($)

12 Months Ended

Dec. 31, 2023

Feb. 01, 2024

Jun. 30, 2023

Cover [Abstract]

Document Type

10-K

Document Annual Report

true

Document Period End Date

Dec. 31, 2023

Current Fiscal Year End Date

--12-31

Document Transition Report

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Entity File Number

001-15891

Entity Registrant Name

NRG Energy, Inc

Entity Incorporation, State or Country Code

DE

Entity Tax Identification Number

41-1724239

Entity Address, Address Line One

910 Louisiana Street

Entity Address, City or Town

Houston

Entity Address, State or Province

TX

Entity Address, Postal Zip Code

77002

City Area Code

713

Local Phone Number

537-3000

Title of 12(b) Security

Common Stock, par value $0.01

Trading Symbol

NRG

Security Exchange Name

NYSE

Entity Well-known Seasoned Issuer

Yes

Entity Voluntary Filers

No

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

ICFR Auditor Attestation Flag

true

Document Financial Statement Error Correction [Flag]

false

Entity Shell Company

false

Entity Public Float

$ 6,266,747,422

Entity Common Stock, Shares Outstanding

208,021,012

Documents Incorporated by Reference

Portions of the Registrant's definitive Proxy Statement relating to its 2024 Annual Meeting of Stockholders

are incorporated by reference into Part III of this Annual Report on Form 10-K

Entity Central Index Key

0001013871

Amendment Flag

false

Document Fiscal Year Focus

2023

Document Fiscal Period Focus

FY

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Audit Information	12 Months Ended
	Dec. 31, 2023
Audit Information [Abstract]
Auditor Name	KPMG LLP
Auditor Location	Philadelphia, PA
Auditor Firm ID	185

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CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenue
Revenue	$ 28,823	$ 31,543	$ 26,989
Operating Costs and Expenses
Cost of operations (excluding depreciation and amortization shown below)	26,526	27,446	20,482
Depreciation and amortization	1,127	634	785
Impairment losses	26	206	544
Selling, general and administrative costs	1,968	1,228	1,293
Provision for credit losses	251	11	698
Acquisition-related transaction and integration costs	119	52	93
Total operating costs and expenses	30,017	29,577	23,895
Gain on sale of assets	1,578	52	247
Operating Income	384	2,018	3,341
Other Income/(Expense)
Equity in earnings of unconsolidated affiliates	16	6	17
Impairment losses on investments	(102)	0	0
Other income, net	47	56	63
Gain/(Loss) on debt extinguishment	109	0	(77)
Interest expense	(667)	(417)	(485)
Total other expense	(597)	(355)	(482)
(Loss)/Income Before Income Taxes	(213)	1,663	2,859
Income tax (benefit)/expense	(11)	442	672
Net (Loss)/Income	(202)	1,221	2,187
Less: Cumulative dividends attributable to Series A Preferred Stock	54	0	0
Net (Loss)/ Income Available for Common Stockholders, basic	(256)	1,221	2,187
Net (Loss)/ Income Available for Common Stockholders, diluted	$ (256)	$ 1,221	$ 2,187
(Loss)/Income Per Share
Weighted average number of common shares outstanding — basic (in shares)	228,000	236,000	245,000
Weighted average number of common shares outstanding — diluted (in shares)	228,000	236,000	245,000
(Loss)/Income per Weighted Average Common Share - Basic (in usd per share)	$ (1.12)	$ 5.17	$ 8.93
(Loss)/Income per weighted average common share — diluted (in usd per share)	$ (1.12)	$ 5.17	$ 8.93

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS)/INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Statement of Comprehensive Income [Abstract]
Net (Loss)/Income	$ (202)	$ 1,221	$ 2,187
Other Comprehensive Income/(Loss), net of tax
Foreign currency translation adjustments	9	(35)	(5)
Defined benefit plans	30	(16)	85
Other comprehensive income/(loss)	39	(51)	80
Comprehensive (Loss)/Income	$ (163)	$ 1,170	$ 2,267

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CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Cash and cash equivalents	$ 541	$ 430
Funds deposited by counterparties	84	1,708
Restricted cash	24	40
Accounts receivable, net	3,542	4,773
Inventory	607	751
Derivative instruments	3,862	7,886
Cash collateral paid in support of energy risk management activities	441	260
Prepayments and other current assets	626	383
Total current assets	9,727	16,231
Property, plant and equipment, net	1,763	1,692
Other Assets
Equity investments in affiliates	42	133
Operating lease right-of-use assets, net	179	225
Goodwill	5,079	1,650
Intangible assets, net	3,927	2,132
Nuclear decommissioning trust fund	0	838
Derivative instruments	2,293	4,108
Deferred income taxes	2,251	1,881
Other non-current assets	777	256
Total other assets	14,548	11,223
Total Assets	26,038	29,146
Current Liabilities
Current portion of long-term debt and finance leases	620	63
Current portion of operating lease liabilities	90	83
Accounts payable	2,325	3,643
Derivative instruments	4,019	6,195
Cash collateral received in support of energy risk management activities	84	1,708
Deferred revenue current	720	176
Accrued expenses and other current liabilities	1,642	1,114
Total current liabilities	9,500	12,982
Other Liabilities
Long-term debt and finance leases	10,133	7,976
Non-current operating lease liabilities	128	180
Nuclear decommissioning reserve	0	340
Nuclear decommissioning trust liability	0	477
Derivative instruments	1,488	2,246
Deferred income taxes	22	134
Deferred revenue non-current	914	10
Other non-current liabilities	947	973
Total other liabilities	13,632	12,336
Total Liabilities	23,132	25,318
Commitments and Contingencies
Stockholders' Equity
Preferred stock	650	0
Common stock; $0.01 par value; 500,000,000 shares authorized; 267,330,470 and 423,897,001 shares issued; and 208,130,950 and 229,561,030 shares outstanding at December 31, 2023 and 2022, respectively	3	4
Additional paid-in capital	3,416	8,457
Retained earnings	820	1,408
Treasury stock, at cost; 59,199,520 and 194,335,971 shares at December 31, 2023 and 2022, respectively	(1,892)	(5,864)
Accumulated other comprehensive loss	(91)	(177)
Total Stockholders' Equity	2,906	3,828
Total Liabilities and Stockholders' Equity	26,038	29,146
Customer relationships, net
Other Assets
Intangible assets, net	2,164	943
Other intangible assets, net
Other Assets
Intangible assets, net	$ 1,763	$ 1,189

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CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($)	Dec. 31, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Preferred stock, shares authorized (in shares)	10,000,000	10,000,000
Preferred stock, shares issued (in shares)	650,000	0
Preferred, shares outstanding (in shares)	650,000	0
Preferred stock, liquidation preference	$ 650
Common stock, par or value (in usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	500,000,000	500,000,000
Common stock, shares issued (in shares)	267,330,470	423,897,001
Common stock, shares outstanding (in shares)	208,130,950	229,561,030
Treasury stock, shares (in shares)	59,199,520	194,335,971

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CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash Flows from Operating Activities
Net (loss)/income		$ (202)	$ 1,221	$ 2,187
Adjustments to reconcile net income to net cash provided by operating activities:
Equity in and distributions from (earnings)/losses of unconsolidated affiliates		(6)	7	20
Depreciation and amortization		1,127	634	785
Accretion of asset retirement obligations		27	55	30
Provision for credit losses		251	11	698
Amortization of nuclear fuel		47	54	51
Amortization of financing costs and debt discounts		52	23	39
(Gain)/Loss on debt extinguishment		(109)	0	77
Amortization of in-the-money contracts and emissions allowances		137	158	106
Amortization of unearned equity compensation		101	28	21
Net gain on sale of assets and disposal of assets		(1,559)	(102)	(261)
Impairment losses		128	206	544
Changes in derivative instruments		2,455	(3,221)	(3,626)
Changes in deferred income taxes and liability for uncertain tax benefits		(92)	382	604
Changes in collateral deposits in support of risk management activities		(1,806)	896	797
Changes in nuclear decommissioning trust liability		0	9	40
Uplift securitization proceeds received/(receivable) from ERCOT		0	689	(689)
Cash (used)/provided by changes in other working capital, net of acquisition and disposition effects:
Accounts receivable - trade		840	(1,560)	(1,232)
Inventory		189	(252)	(61)
Prepayments and other current assets		(233)	17	31
Accounts payable		(1,455)	1,295	476
Accrued expenses and other current liabilities		360	(29)	(55)
Other assets and liabilities		(473)	(161)	(89)
Cash (used)/provided by operating activities		(221)	360	493
Cash Flows from Investing Activities
Payments for acquisitions of businesses and assets, net of cash acquired		(2,523)	(62)	(3,559)
Capital expenditures		(598)	(367)	(269)
Net purchases of emissions allowances		(24)	(6)	0
Investments in nuclear decommissioning trust fund securities		(367)	(454)	(751)
Proceeds from sales of nuclear decommissioning trust fund securities		355	448	710
Proceeds from sale of assets, net of cash disposed		2,007	109	830
Proceeds from insurance recoveries for property, plant and equipment, net		240	0	0
Cash used by investing activities		(910)	(332)	(3,039)
Cash Flows from Financing Activities
Proceeds from issuance of preferred stock, net of fees		635	0	0
Net receipts from settlement of acquired derivatives that include financing elements		342	1,995	938
Payments for share repurchase activity	[1]	(1,172)	(606)	(48)
Payments of dividends to preferred and common stockholders		(381)	(332)	(319)
Proceeds from issuance of long-term debt		731	0	1,100
Payments for short and long-term debt		(523)	(5)	(1,861)
Payments for debt extinguishment costs		0	0	(65)
Payments of debt issuance costs		(32)	(9)	(18)
Proceeds from issuance of common stock		0	0	1
Proceeds from credit facilities		3,020	0	1,415
Repayments to credit facilities		(3,020)	0	(1,415)
Cash (used)/provided by financing activities		(400)	1,043	(272)
Effect of exchange rate changes on cash and cash equivalents		2	(3)	(2)
Net (Decrease)/Increase in Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash		(1,529)	1,068	(2,820)
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at Beginning of Period		2,178	1,110	3,930
Cash and Cash Equivalents, Funds Deposited by Counterparties and Restricted Cash at End of Period		$ 649	$ 2,178	$ 1,110

[1] Includes $(22) million, $(6) million and $(9) million of equivalent shares purchased in lieu of tax withholdings on equity compensation issuances for the years ended December 31, 2023, 2022 and 2021, respectively

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CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - shares shares in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Statement of Cash Flows [Abstract]
Shares purchased in lieu of tax withholding (in shares)	(22)	(6)	(9)

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CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Millions		Total	Cumulative Effect, Period of Adoption, Adjustment	Preferred Stock	Common Stock	Additional Paid-In Capital	Additional Paid-In Capital Cumulative Effect, Period of Adoption, Adjustment	(Accumulated Deficit)/Retained Earnings	(Accumulated Deficit)/Retained Earnings Cumulative Effect, Period of Adoption, Adjustment	Treasury Stock	Accumulated Other Comprehensive Loss
Beginning balance at Dec. 31, 2020		$ 1,680		$ 0	$ 4	$ 8,517		$ (1,403)		$ (5,232)	$ (206)
Increase (Decrease) in Stockholders' Equity
Net income (loss)		2,187						2,187
Other comprehensive income (loss)		80									80
Shares reissuance for ESPP		4				1				3
Share repurchases		(44)								(44)
Equity-based awards activity, net	[1]	12				12
Issuance of common stock		1				1
Common stock dividends and dividend equivalents declared	[2]	(320)						(320)
Ending balance at Dec. 31, 2021		3,600	$ (43)	0	4	8,531	$ (100)	464	$ 57	(5,273)	(126)
Increase (Decrease) in Stockholders' Equity
Net income (loss)		1,221						1,221
Other comprehensive income (loss)		(51)									(51)
Shares reissuance for ESPP		6				2				4
Share repurchases		(595)								(595)
Equity-based awards activity, net	[1]	24				24
Common stock dividends and dividend equivalents declared	[2]	(334)						(334)
Ending balance at Dec. 31, 2022		3,828		0	4	8,457		1,408		(5,864)	(177)
Increase (Decrease) in Stockholders' Equity
Net income (loss)		(202)						(202)
Issuance of Series A Preferred Stock		635		650		(15)
Other comprehensive income (loss)		39									39
Shares reissuance for ESPP		8				2				6
Share repurchases	[3]	(1,160)				(117)				(1,043)
Retirement of treasury stock					(1)	(5,008)				5,009
Equity-based awards activity, net	[1]	97				97
Common stock dividends and dividend equivalents declared	[2]	(352)						(352)
Series A Preferred Stock dividends	[4]	(34)						(34)
Noncontrolling Interest, Increase from Sale of Parent Equity Interest		47									47
Ending balance at Dec. 31, 2023		$ 2,906		$ 650	$ 3	$ 3,416		$ 820		$ (1,892)	$ (91)

[1] Includes $(22) million, $(6) million and $(9) million of equivalent shares purchased in lieu of tax withholding on equity compensation issuances for the years ended December 31, 2023, 2022 and 2021, respectively

[2] Dividends per common share were $1.51, $1.40 and $1.30 for each of the years ended December 31, 2023, 2022 and 2021, respectively

[3] Includes excise tax accrued of $10 million as of December 31, 2023

[4] Dividend per Series A Preferred Stock was $52.96

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CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Nov. 01, 2023
Shares purchased in lieu of tax withholding (in shares)	(22)	(6)	(9)
Dividends paid per share (in usd per share)	$ 1.51	$ 1.40	$ 1.30
Shares repurchased, excise tax accrued	$ 10
Preferred stock, dividends (in usd per share)	$ 52.96
STP
Ownership percentage	44.00%			44.00%

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Nature of Business

12 Months Ended

Dec. 31, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Business

Nature of Business

General

NRG Energy, Inc., or NRG or the Company, sits at the intersection of energy and home services. NRG is a leading energy and home services company fueled by market-leading brands, proprietary technologies, and complementary sales channels. Across the United States and Canada, NRG delivers innovative, sustainable solutions, predominately under the brand names such as NRG, Reliant, Direct Energy, Green Mountain Energy and Vivint, while also advocating for competitive energy markets and customer choice. The Company has a customer base that includes approximately 8 million residential consumers in addition to commercial, industrial, and wholesale customers, supported by approximately 13 GW of generation.

The Company's business is segmented as follows:

•Texas, which includes all activity related to customer, plant and market operations in Texas, other than Cottonwood;

•East, which includes all activity related to customer, plant and market operations in the East;

•West/Services/Other, which includes the following assets and activities: (i) all activity related to customer, plant and market operations in the West and Canada, (ii) the Services businesses (iii) activity related to the Cottonwood facility and other investments;

•Vivint Smart Home; and

•Corporate activities.

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Basis of Presentation and Principles of Consolidation

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

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

The Company identified an error in the previously issued consolidated financial statements for the year ended December 31, 2021 related to the presentation of cash flows associated with certain borrowings and repayments related to the Revolving Credit Facility. The statement of cash flows for the year ended December 31, 2021 has been adjusted to present on a gross basis the borrowings from the Revolving Credit Facility of $1.4 billion and the related repayments of $1.4 billion. The change had no impact to the total cash used by financing activities for the year ended December 31, 2021. We evaluated the materiality of this error both qualitatively and quantitatively and have concluded it is immaterial to the impacted period.

Winter Storm Uri Uplift Securitization Proceeds

The Texas Legislature passed HB 4492 in May 2021 for ERCOT to mitigate exceptionally high price adders and ancillary service costs incurred by LSEs during Winter Storm Uri. HB 4492 authorized ERCOT to obtain $2.1 billion of financing to distribute to LSEs that were charged and paid to ERCOT those highly priced ancillary service and ORDPA during Winter Storm Uri.

In December 2021, ERCOT filed with the PUCT a calculation of each LSE’s share of proceeds based on the settlement methodology. The Company accounted for the proceeds by analogy to the contribution model within ASC 958-605, Not-for-Profit Entities- Revenue Recognition and the grant model within IAS 20, Accounting for Government Grants and Disclosure of Government Assistance, as a reduction to expenses in the consolidated statements of operations in the 2021 annual period for which the proceeds were intended to compensate. The Company received proceeds of $689 million from ERCOT in June 2022.

Credit Losses

In accordance with ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, or ASU No. 2016-13, retail trade receivables are reported on the balance sheet net of the allowance for credit losses within accounts receivables, net. Long-term receivables are recorded net in other non-current assets on the consolidated balance sheet. The Company accrues an allowance for current expected credit losses based on (i) estimates of uncollectible revenues by analyzing accounts receivable aging and current and reasonable forecasts of expected economic factors including, but not limited to, unemployment rates and weather-related events, (ii) historical collections and delinquencies, and (iii) counterparty credit ratings for commercial and industrial customers. The Company writes off customer contract receivable balances against the allowance for credit losses when it is determined a receivable is uncollectible.

The following table represents the activity in the allowance for credit losses for the years ended December 31, 2023, 2022, and 2021:

	Year Ended December 31,
(In millions)	2023		2022		2021
Beginning balance	$	133	$	683	$	67
Acquired balance from Vivint Smart Home	22		—		—
Acquired balance from Direct Energy	—		—		112
Provision for credit losses(a)	251		11		698
Write-offs	(313)		(593)		(224)
Recoveries collected	39		32		30
Other	13		—		—
Ending balance(a)	$	145	$	133	$	683

(a)Includes bilateral finance hedging risk of $(70) million and $403 million accounted for under ASC 815 for the years ended December 31, 2022 and December 31, 2021, respectively

During the year ended December 31, 2022, the provision for credit losses included the Company's loss mitigation efforts recognized as income of $126 million related to Winter Storm Uri. During the year ended December 31, 2021, the provision for credit losses included $596 million of expense due to the impacts of Winter Storm Uri. The increase in write-offs for the periods ended December 31, 2022 and 2021 were primarily due to the resolution of credit losses that occurred during Winter Storm Uri.

Cash and Cash Equivalents

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase.

Funds Deposited by Counterparties

Funds deposited by counterparties consist of cash held by the Company as a result of collateral posting obligations from its counterparties related to NRG's hedging program. The decrease in funds deposited by counterparties is driven by the significant decrease in forward positions as a result of decreases in natural gas and power prices compared to December 31, 2022. Though some amounts are segregated into separate accounts, not all funds are contractually restricted. Based on the Company's intention, these funds are not available for the payment of general corporate obligations; however, they are available for liquidity management. Depending on market fluctuations and the settlement of the underlying contracts, the Company will refund this collateral to the hedge counterparties pursuant to the terms and conditions of the underlying trades. Since collateral requirements fluctuate daily and the Company cannot predict if any collateral will be held for more than twelve months, the funds deposited by counterparties are classified as a current asset on the Company's balance sheet, with an offsetting liability for this cash collateral received within current liabilities.

Restricted Cash

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

	Year Ended December 31,
(In millions)	2023		2022		2021
Cash and cash equivalents	$	541	$	430	$	250
Funds deposited by counterparties	84		1,708		845
Restricted cash	24		40		15
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	649	$	2,178	$	1,110

Restricted cash consists primarily of funds held to satisfy the requirements of certain financing agreements and funds held within the Company's projects that are restricted in their use.

Inventory

Inventory is valued at the lower of weighted average cost or market, and consists principally of natural gas, fuel oil, coal, spare parts and finished goods. The Company removes natural gas inventory as goods are delivered to customers and as they are used in the production of electricity or steam. The Company removes fuel oil and coal inventories as they are used in the production of electricity. The Company removes spare parts inventories when they are used for repairs, maintenance or capital projects. The Company expects to recover the natural gas, fuel oil, coal and spare parts costs in the ordinary course of business. Inventory is valued at the lower of cost or net realizable value with cost being determined on a first in first out basis for finished goods and weighted average cost method for all other inventories. The Company removes finished goods inventories as they are sold to customers. Inventories sold to customers as part of a smart home system are generally capitalized as contract costs. Sales of inventory are classified as an operating activity in the consolidated statements of cash flows.

Property, Plant and Equipment

Property, plant and equipment are stated at cost or, in the case of business acquisitions, fair value; however, impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying values may not be recoverable. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation, other than nuclear fuel, is computed using the straight-line method, while nuclear fuel was amortized based on units of production over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations. For further discussion, see Note 9, Property, Plant and Equipment.

Business Interruption Insurance

The Company carries insurance policies to cover insurable risks including, but not limited to, business interruption. As a result of damage at the Limestone 1 and W.A. Parish 8 units, the Company recorded business interruption insurance settlements of $7 million and $81 million during the year ended December 31, 2023 and December 31, 2022, respectively. Business interruption insurance is recorded to cost of operations in the consolidated statements of operations and cash provided by operating activities in the consolidated statement of cash flows.

Asset Impairments

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

Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures, or ASC 323, which requires that a loss in value of an investment that is an other-than-temporary decline should be recognized. The Company identifies and measures losses in the value of equity method investments based upon a comparison of fair value to carrying value. For further discussion of these matters, refer to Note 11, Asset Impairments.

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis that approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt, or as an asset if the issuance costs relate to revolving debt agreements or certain other financing arrangements.

Intangible Assets

Intangible assets represent contractual rights held by the Company. The Company recognizes specifically identifiable intangible assets including emissions allowances, customer and supply contracts, customer relationships, marketing partnerships, technologies, trade names and fuel contracts when specific rights and contracts are acquired. These intangible assets are amortized based on expected volumes, expected delivery, expected discounted future net cash flows, straight line or units of production basis. As of December 31, 2023 and 2022, the Company had accumulated amortization related to its intangible assets of $3.0 billion and $2.1 billion, respectively.

Emission allowances held-for-sale, which are included in other non-current assets on the Company's consolidated balance sheet, are not amortized; they are carried at the lower of cost or fair value and reviewed for impairment in accordance with ASC 360.

For further discussion, see Note 12, Goodwill and Other Intangibles.

Goodwill

In accordance with ASC 350, Intangibles-Goodwill and Other, or ASC 350, the Company recognizes goodwill for the excess cost of an acquired entity over the net value assigned to assets acquired and liabilities assumed. NRG performs goodwill impairment tests annually, during the fourth quarter, and when events or changes in circumstances indicate that the carrying value may not be recoverable.

The Company may first assesses qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The more-likely-than-not threshold is defined as having a likelihood of more than 50 percent. If it is not more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, there is no goodwill impairment.

In the absence of sufficient qualitative factors indicating that it is more-likely-than-not that no impairment occurred, the Company performs a quantitative assessment by determining the fair value of the reporting unit and comparing the fair value to its book value. If the fair value of the reporting unit exceeds its book value, goodwill of the reporting unit is not considered impaired. If the book value exceeds fair value, the Company recognizes an impairment loss equal to the difference between book value and fair value.

For further discussion of goodwill impairment losses recognized refer to Note 11, Asset Impairments.

Capitalized Contract Costs

Capitalized contract costs represent the costs directly related and incremental to the origination of new contracts, modification of existing contracts or to the fulfillment of the related subscriber contracts. These costs include installed products, commissions, other compensation and the cost of installation of new or upgraded customer contracts. The Company calculates amortization by accumulating all deferred contract costs into separate portfolios based on the initial month of service and amortizes those deferred contract costs on a straight-line basis over the expected period of benefit, consistent with the pattern in which the Company provides services to its customers. The expected period of benefit for customers is approximately five years. The Company updates its estimate of the expected period of benefit periodically and whenever events or circumstances indicate that the expected period of benefit could change significantly. Such changes, if any, are accounted for prospectively as a change in estimate. Amortization of capitalized contract costs related to fulfillment are included in cost of operations and amortization of capitalized contract costs related to customer acquisition are included in selling, general and administrative costs in the consolidated statements of operations. Contract costs not directly related and incremental to the origination of new contracts, modification of existing contracts or to the fulfillment of the related subscriber contracts are expensed as incurred.

Income Taxes

The Company accounts for income taxes using the liability method in accordance with ASC 740, Income Taxes, or ASC 740, which requires that the Company use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences.

The Company has two categories of income tax expense or benefit — current and deferred, as follows:

•Current income tax expense or benefit consists solely of current taxes payable less applicable tax credits, and

•Deferred income tax expense or benefit is the change in the net deferred income tax asset or liability, excluding amounts charged or credited to accumulated other comprehensive income

The Company reports some of its revenues and expenses differently for financial statement purposes than for income tax return purposes, resulting in temporary and permanent differences between the Company's financial statements and income tax returns. The tax effects of such temporary differences are recorded as either deferred income tax assets or deferred income tax liabilities in the Company's consolidated balance sheets. The Company measures its deferred income tax assets and deferred income tax liabilities using income tax rates that are expected to be in effect when the deferred tax is realized.

The Company accounts for uncertain tax positions in accordance with ASC 740, which applies to all tax positions related to income taxes. Under ASC 740, tax benefits are recognized when it is more-likely-than-not that a tax position will be sustained upon examination by the authorities. The benefit recognized from a position is the amount of benefit that has surpassed the more-likely-than-not threshold, as it is more than 50% likely to be realized upon settlement. The Company recognizes interest and penalties accrued related to uncertain tax benefits as a component of income tax expense.

In accordance with ASC 740 and as discussed further in Note 20, Income Taxes, changes to existing net deferred tax assets or valuation allowances or changes to uncertain tax benefits, are recorded to income tax (benefit)/expense.

Contract and Emission Credit Amortization

Assets and liabilities recognized through acquisitions related to the purchase and sale of energy and energy-related products in future periods for which the fair value has been determined to be significantly less or more than market are amortized to revenues or cost of operations over the term of each underlying contract based on actual generation and/or contracted volumes.

Emission credits represent the right to emit a specified amount of certain pollutants, including sulfur dioxide, nitrogen oxides and carbon dioxide, over a compliance period. Emission credits held for use are amortized to cost of operations based on the weighted average cost of the allowances held.

Gross Receipts and Sales Taxes

In connection with its retail sales, the Company records gross receipts taxes on a gross basis in revenues and cost of operations in its consolidated statements of operations. During the years ended December 31, 2023, 2022, and 2021, the Company's revenues and cost of operations included gross receipts taxes of $212 million, $218 million, and $184 million, respectively. Additionally, the Company records sales taxes collected from its taxable retail customers and remitted to the various governmental entities on a net basis; thus, there is no impact on the Company's consolidated statement of operations.

Cost of Operations

Cost of operations includes cost of fuel, purchased energy and other costs of sales, mark-to-market for economic hedging activities, contract and emission credit amortization, operations and maintenance, and other cost of operations.

Cost of Fuel, Purchased Energy and Other Cost of Sales

Cost of fuel is primarily the costs associated with procurement, transportation and storage of natural gas, nuclear fuel, oil and coal to operate the generation portfolio, which is expensed as the fuel is consumed. Purchased energy primarily relates to purchases to supply the Company's customer base, which includes spot market purchases, as well as contracts of various quantities and durations, including Renewable PPAs with third-party developers, which are primarily accounted for as NPNS (see further discussion in Derivative Instruments below). Other cost of sales primarily consists of TDSP expenses.

The cost of fuel is based on actual and estimated fuel usage for the applicable reporting period. The cost to deliver energy and related services to customers is based on actual and estimated supply volumes for the applicable reporting period. A portion of the cost of energy, $240 million, $202 million, and $189 million as of December 31, 2023, 2022, and 2021, respectively, was accrued and consisted of estimated transmission and distribution charges not yet billed by the transmission and distribution utilities.

In estimating supply volumes, the Company considers the effects of historical customer volumes, weather factors and usage by customer class. Transmission and distribution delivery fees are estimated using the same method used for electricity sales and services to retail customers. In addition, ISO fees are estimated based on historical trends, estimated supply volumes and initial ISO settlements. Volume estimates are then multiplied by the supply rate and recorded as cost of operations in the applicable reporting period.

Vivint Smart Home Flex Pay

Under the Flex Pay plan (“Flex Pay”), offered by Vivint Smart Home, subscribers pay separately for smart home products and services (smart home and security). The subscriber has the ability to pay for Vivint Smart Home products in the following three ways: (i) qualified subscribers may finance the purchase through third-party financing providers ("Consumer Financing Program" or “CFP”), (ii) Vivint Smart Home generally offers a limited number of subscribers not eligible for the CFP, but who qualify under Vivint Smart Home underwriting criteria, the option to enter into a retail installment contract directly with Vivint Smart Home or (iii) subscribers may conduct purchases by check, automatic clearing house payments, credit or debit card or by obtaining short term financing (generally no more than six-month installment terms) through Vivint Smart Home.

Although subscribers pay separately for products and services under Flex Pay, the Company has determined that the sale of products and services are one single performance obligation resulting in deferred revenue for the gross amount of products sold. For products financed through the CFP, gross deferred revenues are reduced by (i) any fees the third-party financing provider (“Financing Provider”) is contractually entitled to receive at the time of loan origination, and (ii) the present value of expected future payments due to the Financing Providers. Loans are issued on either an installment or revolving basis with repayment terms ranging from 6 to 60 months.

For certain Financing Provider loans:

•Vivint Smart Home pays a monthly fee based on either the average daily outstanding balance of the installment loans, or the number of outstanding loans.

•Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees.

•Vivint Smart Home also shares liability for credit losses, with Vivint Smart Home being responsible for between 2.6% and 100% of lost principal balances.

Due to the nature of these provisions, the Company records a derivative liability ("CFP Derivative") at its fair value when the Financing Provider originates loans to subscribers, which reduces the amount of estimated revenue recognized on the provision of the services. The derivative liability is reduced as payments are made by Vivint Smart Home to the Financing Provider. Subsequent changes to the fair value of the derivative liability are realized through other income, net in the consolidated statements of operations. For further discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities.

Derivative Instruments

The Company accounts for derivative instruments under ASC 815, which requires the Company to record all derivatives on the balance sheet at fair value and changes in fair value in earnings, unless they qualify for the NPNS exception. The Company's primary derivative instruments are power and natural gas purchase or sales contracts, fuels purchase contracts, the CFP and other energy related commodities used to mitigate variability in earnings due to fluctuation in market prices. In order to mitigate interest rate risk associated with the issuance of the Company's variable rate debt, NRG enters into interest rate swap agreements. In addition, in order to mitigate foreign exchange risk associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements.

As of December 31, 2023 and 2022 the Company did not have derivative instruments that were designated as cash flow or fair value hedges.

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

NRG's trading activities are subject to limits in accordance with the Company's Risk Management Policy. These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative instruments are recognized in earnings.

Mark-to-Market for Economic Hedging Activities

NRG enters into derivative instruments to manage price and delivery risk, optimize physical and contractual assets in the portfolio and manage working capital requirements. The mark-to-market for economic hedging activities are recognized to revenues or cost of operations during the reporting period.

Operations and Maintenance and Other Cost of Operations

Operations and maintenance costs include major and other routine preventative (planned outage) and corrective (forced outage) maintenance activities to ensure the safe and reliable operation of the Company's generation portfolio in compliance

with all local, state and federal requirements. Operations and maintenance costs are also costs associated with retaining and maintaining the Company's customer base, such as call center support, portfolio maintenance and data analytics. Other cost of operations primarily includes gross receipts taxes, insurance, property taxes and asset retirement obligation expense.

Foreign Currency Translation and Transaction Gains and Losses

The local currencies are generally the functional currency of NRG's foreign operations. Foreign currency denominated assets and liabilities are translated at end-of-period rates of exchange. Revenues, expenses, and cash flows are translated at the weighted-average rates of exchange for the period. The resulting currency translation adjustments are not included in the Company's consolidated statements of operations for the period, but are accumulated and reported as a separate component of stockholders' equity until sale or complete or substantially complete liquidation of the net investment in the foreign entity takes place. Foreign currency transaction gains or losses are reported within other income, net in the Company's consolidated statements of operations. For the years ended December 31, 2023, 2022 and 2021, amounts recognized as foreign currency transaction gains/(losses) were immaterial. The Company's cumulative translation adjustment balances as of December 31, 2023, 2022, and 2021 were $(43) million, $(55) million, and $(8) million, respectively.

Concentrations of Credit Risk

Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of trust funds, accounts receivable, notes receivable, derivatives and investments in debt securities. Trust funds are held in accounts managed by experienced investment advisors. Certain accounts receivable, notes receivable, and derivative instruments are concentrated within entities engaged in the energy industry. These industry concentrations may impact the Company's overall exposure to credit risk, either positively or negatively, in that the customers may be similarly affected by changes in economic, industry or other conditions. Receivables and other contractual arrangements are subject to collateral requirements under the terms of enabling agreements. However, the Company believes that the credit risk posed by industry concentration is offset by the diversification and creditworthiness of its customer base. See Note 5, Fair Value of Financial Instruments, for a further discussion of derivative concentrations.

Asset Retirement Obligations

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

Upon initial recognition of a liability for an ARO, the Company capitalizes the asset retirement cost by increasing the carrying amount of the related long-lived asset by the same amount. Over time, the liability is accreted to its future value, while the capitalized cost is depreciated over the useful life of the related asset. See Note 14, Asset Retirement Obligations, for a further discussion of AROs.

Pensions and Other Postretirement Benefits

The Company offers pension benefits through a defined benefit pension plan. In addition, the Company provides postretirement health and welfare benefits for certain groups of employees. The Company accounts for pension and other postretirement benefits in accordance with ASC 715, Compensation — Retirement Benefits, or ASC 715. The Company recognizes the funded status of the Company's defined benefit plans in the statement of financial position and records an offset for gains and losses as well as all prior service costs that have not been included as part of the Company's net periodic benefit cost to other comprehensive income. The determination of the Company's obligation and expenses for pension benefits is dependent on the selection of certain assumptions. These assumptions determined by management include the discount rate, the expected rate of return on plan assets and the rate of future compensation increases. The Company's actuarial consultants assist in determining assumptions for such items as retirement age. The assumptions used may differ materially from actual results, which may result in a significant impact to the amount of pension obligation or expense recorded by the Company.

The Company measures the fair value of its pension assets in accordance with ASC 820, Fair Value Measurements and Disclosures, or ASC 820. For further discussion, see Note 15, Benefit Plans and Other Postretirement Benefits.

Stock-Based Compensation

The Company accounts for its stock-based compensation in accordance with ASC 718, Compensation — Stock Compensation, or ASC 718. The fair value of the Company's performance stock units is estimated on the date of grant using a Monte Carlo valuation model. NRG uses the Company's common stock price on the date of grant as the fair value of the Company's deferred stock units. Forfeiture rates are estimated based on an analysis of the Company's historical forfeitures, employment turnover, and expected future behavior. The Company recognizes compensation expense for both graded and cliff

vesting awards on a straight-line basis over the requisite service period for the entire award. For further discussion, see Note 21, Stock-Based Compensation.

Investments Accounted for by the Equity Method

The Company has investments in various domestic energy projects, as well as one Australian project. The equity method of accounting is applied to such investments in affiliates, which include joint ventures and partnerships, because the ownership structure prevents the Company from exercising a controlling influence over the operating and financial policies of the projects. Under this method, equity in pre-tax income or losses of domestic partnerships and, generally, in the net income or losses of its Australian project, are reflected as equity in earnings of unconsolidated affiliates. Distributions from equity method investments that represent earnings on the Company's investment are included within cash flows from operating activities and distributions from equity method investments that represent a return of the Company's investment are included within cash flows from investing activities. For further discussion, see Note 17, Investments Accounted for by the Equity Method and Variable Interest Entities.

Sale-Leaseback Arrangements

NRG is party to sale-leaseback arrangements that provide for the sale of certain assets to a third-party and simultaneously leases back the same asset to the Company. If the seller-lessee transfers control of the underlying assets to the buyer-lessor, the arrangement is accounted for under ASC 842-40, Sale-Leaseback Transactions. These arrangements are classified as operating leases on the Company's consolidated balance sheets.

Marketing and Advertising Costs

The Company expenses its marketing and advertising costs as incurred and includes them within selling, general and administrative costs. The costs of tangible assets used in advertising campaigns are recorded as fixed assets or deferred advertising costs and amortized as advertising costs over the shorter of the useful life of the asset or the advertising campaign. The Company has several long-term sponsorship arrangements. Payments related to these arrangements are deferred and expensed over the term of the arrangement. Advertising expenses for the years ended December 31, 2023, 2022, and 2021 were $185 million, $82 million, and $109 million, respectively.

Business Combinations

The Company accounts for its business combinations in accordance with ASC 805, Business Combinations, or ASC 805, which requires an acquirer to recognize and measure in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at fair value at the acquisition date. The Company also recognizes and measures the goodwill acquired or a gain from a bargain purchase in the business combination. In addition, transaction costs are expensed as incurred.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.

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

Reclassifications

Certain prior period amounts have been reclassified for comparative purposes. The reclassifications did not affect results from operations, net assets or cash flows.

Recent Accounting Developments - Guidance Adopted in 2023

ASU 2021-08 — In October 2021, the FASB issued ASU No. 2021-08, Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers, or ASU 2021-08, which requires that an entity recognize and measure contract assets and contract liabilities acquired in a business combination as if it had originated the contracts in accordance with ASC 606, Revenue from Contracts with Customers. As a result, an acquirer should recognize and measuring the acquired contract assets and contract liabilities consistently with how they were recognized and measured in the

acquiree’s financial statements. The amendments per ASU 2021-08 apply only to contract assets and contract liabilities from contracts with customers, as defined in Topic 606, such as refund liabilities and upfront payments to customers. Assets and liabilities under related Topics, such as deferred costs under Subtopic 340-40, Other Assets and Deferred Costs — Contracts with Customers, are not within the scope of amendments per ASU 2021-08. The Company adopted ASU 2021-08 prospectively effective January 1, 2023 and applied the amended requirements to the acquisition of Vivint Smart Home.

Recent Accounting Developments - Guidance Not Yet Adopted

ASU 2023-07 – In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280) – Improvements to Reportable Segment Disclosures, or ASU 2023-07. The guidance in ASU 2023-07 enhances reportable segment disclosure requirements by requiring disclosure of significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss, an amount and description of its composition for other segment items and interim disclosures of a reportable segment’s profit or loss and assets. The amendments of ASU 2023-07 are effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, with early adoption permitted and should be applied retrospectively for all prior periods presented in the financial statements. The Company is currently evaluating the impact of adopting ASU 2023-07 on its disclosures.

ASU 2023-09 – In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740) – Improvements to Income Tax Disclosures, or ASU 2023-09. The guidance in ASU 2023-09 enhances income tax disclosures by requiring disclosure of specific categories in the effective tax rate reconciliation and additional information for reconciling items that meet a quantitative threshold. Further the amendments of ASU 2023-09 require certain disclosures on income tax expense and income taxes paid. ASU 2023-09 is effective for annual periods beginning after December 15, 2024, with early adoption permitted. The amendments of ASU 2023-09 may be applied on a prospective or retrospective basis. The Company is currently evaluating the impact of adopting ASU 2023-09 on its disclosures.

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Revenue Recognition

12 Months Ended

Dec. 31, 2023

Revenue from Contract with Customer [Abstract]

Revenue Recognition

Revenue Recognition

The Company's policies with respect to its various revenue streams are detailed below. The Company generally 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.

Retail Revenue

Gross revenues for energy sales and services to retail customers are recognized as the Company transfers the promised goods and services to the customer. Payment terms are generally 15 to 60 days. For the majority of its electricity and natural gas contracts, the Company’s performance obligation with the customer is satisfied over time and performance obligations for its electricity and natural gas products are recognized as the customer takes possession of the product. The Company also allocates the contract consideration to distinct performance obligations in a contract for which the timing of the revenue recognized is different. Additionally, customer discounts and incentives reduce the contract consideration and are recognized over the term of the contract.

Energy sales and services that have been delivered but not billed by period end are estimated. Accrued unbilled revenues are based on estimates of customer usage since the date of the last meter reading provided by the independent system operators, utilities, or electric distribution companies. Volume estimates are based on daily forecasted volumes and estimated customer usage by class. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class. Estimated amounts are adjusted when actual usage is known and billed.

As contracts for retail electricity and natural gas can be for multi-year periods, 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 that vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the amount of any unsatisfied performance obligations will vary based on customer usage, which will depend on factors such as weather and customer activity and therefore it is not practicable to estimate such amounts.

Vivint Smart Home Retail Revenue

Vivint Smart Home offers its subscribers combinations of smart home products and services, which together create an integrated smart home system that allows the Company's subscribers to monitor, control and protect their homes. As the products and services included in the subscriber's contract are integrated and highly interdependent, and because the products (including installation) and services must work together to deliver the monitoring, controlling and protection of their home, the Company has concluded that the products and services contracted for by the subscriber are generally not distinct within the context of the contract and, therefore, constitute a single, combined performance obligation. Revenues for this single, combined performance obligation are recognized on a straight-line basis over the subscriber's contract term, which is the period in which the parties to the contract have enforceable rights and obligations. The Company has determined that certain contracts that do not require a long-term commitment for monitoring services by the subscriber contain a material right to renew the contract,

because the subscriber does not have to purchase the products upon renewal. Proceeds allocated to the material right are recognized over the expected period of benefit. The majority of Vivint Smart Home's subscription contracts are five years and are generally non-cancelable. These contracts generally convert into month-to-month agreements at the end of the initial term, while some subscribers are month-to-month from inception. Payment for Vivint Smart Home services is generally due in advance on a monthly basis, with payment terms up to 30 days. Product sales and other one-time fees are invoiced to subscribers at time of sale. Revenues for any products or services that are considered separate performance obligations are recognized upon delivery. Payments received or billed in advance are reported as deferred revenues.

Energy Revenue

Both physical and financial transactions consist of revenues billed to a third-party at either market or negotiated contract terms to optimize the financial performance of the Company's generating facilities. Payment terms vary from 5 to 55 days. Electric energy revenue is recognized upon transmission to the customer over time, using the output method for measuring progress of satisfaction of performance obligations. Physical transactions, or the sale of generated electricity to meet supply and demand, are recorded on a gross basis in the Company's consolidated statements of operations. The Company applies the invoicing practical expedient in recognizing energy revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date. Financial transactions used to hedge the sale of electricity are recorded net within revenues in the consolidated statements of operations in accordance with ASC 815.

Ancillary revenues, included in Other revenue, are recognized over time as the obligation is fulfilled, using the output method for measuring progress of satisfaction of performance obligations.

Capacity Revenue

The Company's largest sources of capacity revenues are capacity auctions in PJM and NYISO. Capacity revenues also include revenues billed to a third-party at either market or negotiated contract terms for making installed generation and demand response capacity available in order to satisfy system integrity and reliability requirements. Payment terms vary from 15 to 55 days. Capacity revenues are recognized over time, using the output method for measuring progress of satisfaction of performance obligations. The Company applies the invoicing practical expedient in recognizing capacity revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date.

Performance Obligations

As of December 31, 2023, estimated future fixed fee performance obligations are $1.4 billion, $1.0 billion, $756 million, $468 million and $176 million for fiscal years 2024, 2025, 2026, 2027 and 2028, respectively. These performance obligations include Vivint Smart Home products and services as well as cleared auction MWs in the PJM, NYISO and MISO capacity auctions. The cleared auction MWs are subject to penalties for non-performance.

Disaggregated Revenue     

The following tables represent the Company’s disaggregation of revenue from contracts with customers for the years ended December 31, 2023, 2022, and 2021:

	For the Year Ended December 31, 2023
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate/Eliminations		Total
Retail revenue
Home(b)	$	6,538	$	2,195	$	1,890	$	1,549	$	(1)	$	12,171
Business	3,492		9,751		2,053		—		—		15,296
Total retail revenue(b)	10,030		11,946		3,943		1,549		(1)		27,467
Energy revenue(c)	77		291		185		—		—		553
Capacity revenue(c)	—		197		2		—		(2)		197
Mark-to-market for economic hedging activities(d)	—		57		103		—		(16)		144
Contract amortization	—		(32)		—		—		—		(32)
Other revenue(c)	369		88		48		—		(11)		494
Total revenue	10,476		12,547		4,281		1,549		(30)		28,823
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		17		35		—		—		52
Less: Realized and unrealized ASC 815 revenue	29		364		138		—		(16)		515
Total revenue from contracts with customers	$	10,447	$	12,166	$	4,108	$	1,549	$	(14)	$	28,256
(a) Includes results of operations following the acquisition date of March 10, 2023
(b) Home includes Services and Vivint Smart Home
(c) The following amounts of retail, energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home		Corporate/Eliminations		Total
Retail revenue	$	—	$	74	$	—	$	—	$	—	$	74
Energy revenue	—		162		13		—		1		176
Capacity revenue	—		73		—		—		—		73
Other revenue	29		(2)		22		—		(1)		48
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	6,388	$	2,088	$	2,286	$	(1)	$	10,761
Business	3,229		13,768		1,964		—		18,961
Total retail revenue(b)	9,617		15,856		4,250		(1)		29,722
Energy revenue(b)	111		641		466		32		1,250
Capacity revenue(b)	—		232		40		—		272
Mark-to-market for economic hedging activities(c)	2		(30)		(56)		1		(83)
Contract amortization	—		(40)		1		—		(39)
Other revenue(b)	327		104		5		(15)		421
Total revenue	10,057		16,763		4,706		17		31,543
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(7)		41		1		35
Less: Realized and unrealized ASC 815 revenue	(2)		84		(93)		31		20
Total revenue from contracts with customers	$	10,059	$	16,686	$	4,758	$	(15)	$	31,488
(a) Home includes Services
(b) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue	$	—	$	110	$	—	$	—	$	110
Energy revenue	—		(31)		(8)		31		(8)
Capacity revenue	—		33		—		—		33
Other revenue	(4)		2		(29)		(1)		(32)
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	5,659	$	1,832	$	2,059	$	(1)	$	9,549
Business	2,745		10,030		1,237		—		14,012
Total retail revenue	8,404		11,862		3,296		(1)		23,561
Energy revenue(c)	329		508		371		7		1,215
Capacity revenue(c)	—		718		57		—		775
Mark-to-market for economic hedging activities(d)	(3)		(88)		(86)		13		(164)
Contract amortization	—		(26)		(4)		—		(30)
Other revenue(b)(c)	1,565		51		25		(9)		1,632
Total revenue	10,295		13,025		3,659		10		26,989
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(25)		3		—		(22)
Less: Realized and unrealized ASC 815 revenue	130		184		(96)		16		234
Total revenue from contracts with customers	$	10,165	$	12,866	$	3,752	$	(6)	$	26,777
(a) Home includes Services
(b) Other Revenue in Texas includes ancillary revenues of $1.3 billion driven by high pricing during Winter Storm Uri
(c) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Energy revenue	$	—	$	131	$	2	$	3	$	136
Capacity revenue	—		149		—		—		149
Other revenue	133		(8)		(12)		—		113
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

Contract Balances

The following table reflects the contract assets and liabilities included in the Company's balance sheet as of December 31, 2023 and 2022:

(In millions)	December 31, 2023		December 31, 2022
Capitalized contract costs(a)	$	706	$	126
Accounts receivable, net - Contracts with customers	3,395		4,704
Accounts receivable, net - Accounted for under topics other than ASC 606	136		64
Accounts receivable, net - Affiliate	11		5
Total accounts receivable, net	$	3,542	$	4,773
Unbilled revenues (included within Accounts receivable, net - Contracts with customers)	$	1,493	$	1,952
Deferred revenues (b)	$	1,634	$	186

(a)Amortization of capitalized contract costs for the years ended December 31, 2023, 2022 and 2021 were $168 million, $86 million and $95 million, respectively

(b)Deferred revenues from contracts with customers for the years ended December 31, 2023 and 2022 were approximately $1.6 billion and $175 million, respectively. The increase in deferred revenue balances from December 31, 2023 to 2022 was primarily due to the acquisition of Vivint Smart Home

The revenue recognized from contracts with customers during the years ended December 31, 2023 and 2022 relating to the deferred revenue balance at the beginning of each period was $168 million and $184 million, respectively. The change in the revenue recognized from contracts with customers relating to the deferred revenue balances at the beginning of the years ended December 31, 2023 and 2022 was primarily due to the timing difference of when consideration was received and when the performance obligation was transferred.

The Company's capitalized contract costs consist of commission payments, broker fees and other costs that represent incremental costs of obtaining the contract with customers for which the Company expects to recover. Capitalized contract costs are amortized on a straight-line basis over the expected period of benefit of five years. As a practical expedient, the Company expenses the incremental costs of obtaining a contract if the amortization period of the asset would have been one year or less.

When the Company receives consideration from the customer that is in excess of the amount due, such consideration is reclassified to deferred revenue, which represents a contract liability. Smart home products and services performance obligations are recognized over the customer's contract term, which is generally three to five years. Energy contract liabilities are generally recognized to revenue in the next period as the Company satisfies its performance obligations.

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Acquisitions and Dispositions

12 Months Ended

Dec. 31, 2023

Discontinued Operations and Disposal Groups [Abstract]

Acquisitions and Dispositions

Acquisitions and Dispositions

Acquisitions

2023 Acquisitions

Vivint Smart Home Acquisition

On March 10, 2023 (the "Acquisition Closing Date"), the Company completed the acquisition of Vivint Smart Home, Inc., pursuant to the Agreement and Plan of Merger, dated as of December 6, 2022, by and among the Company, Vivint Smart Home, Inc. and Jetson Merger Sub, Inc., a wholly-owned subsidiary of the Company (“Merger Sub”) pursuant to which Merger Sub merged with and into Vivint Smart Home, Inc., with Vivint Smart Home, Inc. surviving the merger as a wholly-owned subsidiary of the Company. Dedicated to redefining the home experience with intelligent products and services, Vivint Smart Home brought approximately two million subscribers to NRG. Vivint Smart Home's single, expandable platform incorporates artificial intelligence and machine learning into its operating system and its vertically integrated business model includes hardware, software, sales, installation, customer service and technical support and professional monitoring, enabling superior subscriber experiences and a complete end-to-end smart home experience. The acquisition accelerated the realization of NRG's consumer-focused growth strategy and creates a leading essential home services platform fueled by market-leading brands, unparalleled insights, proprietary technologies and complementary sales channels.

NRG paid $12 per share, or approximately $2.6 billion in cash. The Company funded the acquisition using:

•proceeds of $724 million from newly issued $740 million 7.000% Senior Secured First Lien Notes due 2033, net of issuance costs and discount;

•proceeds of $635 million from newly issued $650 million 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, net of issuance costs;

•proceeds of approximately $900 million drawn from its Revolving Credit Facility and Receivables Securitization Facilities; and

•cash on hand.

In February 2023, the Company increased its Revolving Credit Facility by $600 million to meet the additional liquidity requirements related to the acquisition. For further discussion, see Note 13, Long-term Debt and Finance Leases.

Acquisition costs of $38 million and $17 million for the years ended December 31, 2023 and 2022, respectively, are included in acquisition-related transaction and integration costs in the Company's consolidated statement of operations.

The acquisition has been recorded as a business combination under ASC 805, with identifiable assets and liabilities acquired recorded at their estimated Acquisition Closing Date fair value. The total consideration of $2.623 billion includes:

	(In millions)
Vivint Smart Home, Inc. common shares outstanding as of March 10, 2023 of 216,901,639 at $12.00 per share	$	2,603
Other Vivint Smart Home, Inc. equity instruments (Cash out RSUs and PSUs, Stock Appreciation Rights, Private Placement Warrants)	6
Total Cash Consideration	$	2,609
Fair value of acquired Vivint Smart Home, Inc. equity awards attributable to pre-combination service	14
Total Consideration	$	2,623

The purchase price was allocated as follows as of December 31, 2023:

	(In millions)
Current Assets
Cash and cash equivalents	$	120
Accounts receivable, net	60
Inventory	113
Prepayments and other current assets	37
Total current assets	330
Property, plant and equipment, net	49
Other Assets
Operating lease right-of-use assets, net	35
Goodwill(a)	3,494
Intangible assets, net(b):
Customer relationships	1,740
Technology	860
Trade names	160
Sales channel contract	10
Intangible assets, net	2,770
Deferred income taxes	382
Other non-current assets	14
Total other assets	6,695
Total Assets	$	7,074
Current Liabilities
Current portion of long-term debt and finance leases	$	14
Current portion of operating lease liabilities	13
Accounts payable	109
Derivative instruments	80
Deferred revenue current	518
Accrued expenses and other current liabilities	207
Total current liabilities	941
Other Liabilities
Long-term debt and finance leases	2,572
Non-current operating lease liabilities	28
Derivative instruments	32
Deferred income taxes	18
Deferred revenue non-current	837
Other non-current liabilities	23
Total other liabilities	3,510
Total Liabilities	$	4,451
Vivint Smart Home Purchase Price	$	2,623

(a)Goodwill arising from the acquisition is attributed to the value of the platform acquired, cross-selling opportunities, subscriber growth and the synergies expected from combining the operations of Vivint Smart Home with NRG's existing businesses. None of the goodwill recorded will be deductible for tax purposes

(b)The weighted average amortization period for total amortizable intangible assets is approximately ten years

Fair Value Measurement of Intangible Assets

The fair values of intangible assets as of the Acquisition Closing Date were measured primarily based on significant inputs that are observable and unobservable in the market and thus represent Level 2 and Level 3 measurements, respectively. Significant inputs were as follows:

Customer relationships – Customer relationships, reflective of Vivint Smart Home’s subscriber base, were valued using an excess earning method of the income approach, and is classified as Level 3. Under this approach, the Company estimated the present value of expected future cash flows resulting from existing subscriber relationships, considering attrition and charges for contributory assets (such as net working capital, fixed assets, workforce, trade names and technology) utilized in the business, discounted based on the required rate of return on the acquired intangible asset. The subscriber relationships are amortized to depreciation and amortization, ratably based on discounted future cash flows. The weighted average amortization period is twelve years.

Technology – Developed technology was valued using a "relief from royalty" method of the income approach, and is classified as Level 3. Under this approach, the fair value was estimated to be the present value of royalties saved which assumed the value of the asset based on discounted cash flows of the amount that would be paid by a hypothetical market participant had they not owned the asset and instead licensed the asset from another company. The estimated cash flows from the developed technology considered the obsolescence factor and was discounted based on the required rate of return on the acquired intangible asset. The developed technology is amortized to depreciation and amortization, ratably based on discounted future cash flows. The weighted average amortization period is five years.

Trade names – Trade names were valued using a "relief from royalty" method of the income approach, and is classified as Level 3. Under this approach, the fair value is estimated to be the present value of royalties saved which assumed the value of the asset based on discounted cash flows of the amount that would be paid by a hypothetical market participant had they not owned the asset and instead licensed the asset from another company. The estimated cash flows from the trade names considered the expected probable use of the asset and was discounted based on the required rate of return on the acquired intangible asset. The trade names are amortized to depreciation and amortization, on a straight line basis, over an amortization period of ten years.

Fair Value Measurement of Acquired Vivint Smart Home Debt

The Company acquired $2.7 billion in aggregate principal of Vivint Smart Home’s 2027 Senior Secured Notes, 2029 Senior notes and 2028 Senior Secured Term Loan (together, the "Acquired Vivint Smart Home Debt") which were recorded at fair value as of the Acquisition Closing Date. The difference between the fair value at the Acquisition Closing Date and the principal outstanding of the Acquired Vivint Smart Home Debt, of $152 million, is being amortized through interest expense over the remaining term of the debt. The Acquired Vivint Smart Home Debt is classified as Level 2 and were measured at fair value using observable market inputs based on interest rates at the Acquisition Closing Date. For additional discussion, see Note 13, Long-term Debt and Finance Leases.

Fair Value Measurement of Derivatives Liabilities

The derivative liabilities are recorded in connection with the contractual future payment obligations with the financing providers under Vivint Smart Home’s Consumer Financing Program. The fair values of the derivatives liabilities as of the Acquisition Closing Date were valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates. These derivatives are classified as Level 3 and changes to the fair value are recorded through other income, net in the consolidated statement of operations. For additional discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities.

Supplemental Pro Forma Financial Information

The following table provides unaudited pro forma combined financial information of NRG and Vivint Smart Home, after giving effect to the Vivint Smart Home acquisition and related financing transactions as if they had occurred on January 1, 2021. The pro forma financial information has been prepared for illustrative and informational purposes only, and is not intended to project future operating results or be indicative of what the Company's financial performance would have been had the transactions occurred on the date indicated. No effect has been given to prospective operating synergies.

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Total operating revenues	$	29,109	$	33,225	$	28,468
Net (loss)/income	(3)		1,136		1,574

Amounts above reflect certain pro forma adjustments that were directly attributable to the Vivint Smart Home acquisition. These adjustments include the following:

(i)Income statement effects of fair value adjustments based on the purchase price allocation including amortization of intangible assets, reversal of historical Vivint Smart Home amortization of capitalized contract costs and reversal of historical Vivint Smart Home other income recorded for the change in fair value of warrant derivative liabilities, as the warrants are assumed to be cashed out upon the Acquisition Closing Date.

(ii)One-time expenses directly related to the acquisition.

(iii)Adjustments to reflect all acquisition and related transactions costs in the year ended December 31, 2021.

(iv)Interest expense assumes the financing transactions directly attributable to the Vivint Smart Home acquisition occurred on January 1, 2021.

(v)Adjustments related to recording Vivint Smart Home's historical debt at Acquisition Closing Date fair value.

(vi)Adjustments to reflect the write-off of short-term deferred financing costs related to the bridge facility put in place for the acquisition prior to securing permanent financing during the year ended December 31, 2021 instead of the year ended December 31, 2023.

(vii) Income tax effect of the acquisition accounting adjustments and financing adjustments (adjusted for permanent book/tax differences) based on combined blended federal/state tax rate for all periods presented.

2021 Acquisitions

Direct Energy Acquisition

On January 5, 2021, the Company acquired all of the issued and outstanding common shares of Direct Energy, which had been a North American subsidiary of Centrica plc. Direct Energy is a leading retail provider of electricity, natural gas, and home and business energy related products and services in North America, with operations in all 50 U.S. states and 8 Canadian provinces. The acquisition increased NRG's retail portfolio by over 3 million customers and strengthened its integrated model. It also broadened the Company's presence in the Northeast and into states and locales where it did not previously operate, supporting NRG's objective to diversify its business.

The Company paid an aggregate purchase price of $3.625 billion in cash and total purchase price adjustment of $99 million, resulting in an adjusted purchase price of $3.724 billion.

Acquisition costs of $25 million for the year ended December 31, 2021 are included in acquisition-related transaction and integration costs in the Company's consolidated statement of operations.

The acquisition has been recorded as a business combination under ASC 805 with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the acquisition date. The purchase price was allocated as follows as of December 31, 2021:

	(In millions)
Current Assets
Cash and cash equivalents	$	152
Funds deposited by counterparties	21
Restricted cash	9
Accounts receivable, net	1,802
Inventory	106
Derivative instruments	1,014
Cash collateral paid in support of energy risk management activities	233
Prepayments and other current assets	173
Total current assets	3,510
Property, plant and equipment, net	151
Other Assets
Goodwill(a)	1,250
Intangible assets, net:
Customer relationships(b)	1,277
Customer and supply contracts(b)	610
Trade names(b)	310
Renewable energy credits	124
Total intangible assets, net	2,321
Derivative instruments	531
Other non-current assets	31
Total other assets	4,133
Total Assets	$	7,794
Current Liabilities
Accounts payable	$	1,116
Derivative instruments	1,266
Cash collateral received in support of energy risk management activities	21
Accrued expenses and other current liabilities	670
Total current liabilities	3,073
Other Liabilities
Derivative instruments	562
Deferred income taxes	320
Other non-current liabilities	115
Total other liabilities	997
Total Liabilities	$	4,070
Direct Energy Purchase Price	$	3,724

(a)Goodwill arising from the acquisition was attributed to the value of the platform acquired and the synergies expected from combining the operations of Direct Energy with NRG's existing businesses. Goodwill was allocated to the Texas, East, and West/Services/Other segments of $427 million, $648 million and $175 million, respectively. Goodwill deductible for tax purposes was $322 million

(b)As of January 5, 2021, the weighted average amortization period for total amortizable intangible assets was 12 years

Dispositions

2023 Dispositions

Sale of the 44% equity interest in STP

On November 1, 2023, the Company closed on the sale of its 44% equity interest in STP to Constellation Energy Generation ("Constellation"). Proceeds of $1.75 billion were reduced by working capital and other adjustments of $96 million, resulting in net proceeds of $1.654 billion. The Company recorded a gain on the sale of $1.2 billion within the Texas region of operations. For discussion of the litigation matter related to the transaction, see Note 23, Commitments and Contingencies.

The Company recorded income before income taxes from its 44% equity interest in STP as follows:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Income before income taxes(a)	$	206	$	362	$	829

(a)Excludes the impact of the Company's hedges at the portfolio level

Sale of Gregory

On October 2, 2023, the Company closed on the sale of its 100% ownership in the Gregory natural gas generating facility in Texas for $102 million. The Company recorded a gain on the sale of $82 million.

Sale of Astoria

On January 6, 2023, the Company closed on the sale of land and related generation assets from the Astoria site, within the East region of operations, for proceeds of $212 million, subject to transaction fees of $3 million and certain indemnifications, resulting in a $199 million gain. As part of the transaction, NRG entered into an agreement to lease the land back for the purpose of operating the Astoria gas turbines. Decommissioning was completed in December 2023 and the lease agreement has been terminated.

2022 Dispositions

Sale of Watson

On June 1, 2022, the Company closed on the sale of its 49% ownership in the Watson natural gas generating facility for $59 million. The Company recorded a gain on the sale of $46 million.

2021 Dispositions

Sale of 4,850 MW of Fossil generating assets

On December 1, 2021, the Company closed the previously announced sale of approximately 4,850 MWs of fossil generating assets from its East and West regions to Generation Bridge, an affiliate of ArcLight Capital Partners. Proceeds of $760 million were reduced by working capital and other adjustments of $140 million, resulting in net proceeds of $620 million. The Company recorded a gain of $207 million from the sale, which includes the $39 million indemnification liability recorded as discussed below. As part of the transaction, NRG entered into a tolling agreement for the 866 MW Arthur Kill plant in New York City through April 2025.

As part of the agreement to sell the fossil generating assets, NRG has agreed to indemnify Generation Bridge for certain future environmental compliance costs up to $39 million. The indemnity term will expire on December 1, 2028. The Company has recorded the liability within accrued expenses and other current liabilities and other non-current liabilities.

Sale of Agua Caliente

On February 3, 2021, the Company closed on the sale of its 35% ownership in the Agua Caliente solar project to Clearway Energy, Inc. for $202 million. NRG recognized a gain on the sale of $17 million, including cash disposed of $7 million.

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Fair Value of Financial Instruments

12 Months Ended

Dec. 31, 2023

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value of Financial Instruments

For cash and cash equivalents, funds deposited by counterparties, restricted cash, accounts and other receivables, accounts payable and cash collateral paid and received in support of energy risk management activities, the carrying amount approximates fair value because of the short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy.

The estimated carrying value and fair value of the Company's long-term debt, including current portion, is as follows:

	As of December 31,
	2023				2022
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Convertible Senior Notes	$	575	$	739	$	575	$	576
Other long-term debt, including current portion	10,219		9,835		7,523		6,432
Total long-term debt, including current portion(a)	$	10,794	$	10,574	$	8,098	$	7,008

(a)Excludes deferred financing 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 and the Vivint Smart Home Senior Secured Term Loan are based on quoted market prices and are classified as Level 2 within the fair value hierarchy.

Fair Value Accounting under ASC 820

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

•Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date. NRG's financial assets and liabilities utilizing Level 1 inputs include active exchange-traded securities, energy derivatives, and trust fund investments.

•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. NRG's financial assets and liabilities utilizing Level 2 inputs include fixed income securities, exchange-based derivatives, and over the counter derivatives such as swaps, options and forward contracts.

•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. NRG's financial assets and liabilities utilizing Level 3 inputs include infrequently-traded, non-exchange-based derivatives and commingled investment funds, and are measured using present value pricing models.

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 in its entirety.

Recurring Fair Value Measurements

Derivative assets and liabilities, debt securities, equity securities and trust fund investments, which were comprised of various U.S. debt and equity securities, are carried at fair market value.

The following tables present assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:

	As of December 31, 2023
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	21	$	—	$	21	$	—
Derivative assets:
Interest rate contracts	12		—		12		—
Foreign exchange contracts	5		—		5		—
Commodity contracts	6,138		1,334		4,470		334
Equity securities measured using net asset value practical expedient (classified within other non-current assets)	6
Total assets	$	6,182	$	1,334	$	4,508	$	334
Derivative liabilities:
Interest rate contracts	$	8	$	—	$	8	$	—
Foreign exchange contracts	9		—		9		—
Commodity contracts	5,356		1,413		3,728		215
Consumer Financing Program	134		—		—		134
Total liabilities	$	5,507	$	1,413	$	3,745	$	349

	As of December 31, 2022
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	19	$	—	$	19	$	—
Nuclear trust fund investments:
Cash and cash equivalents	15		15		—		—
U.S. government and federal agency obligations	86		84		2		—
Federal agency mortgage-backed securities	101		—		101		—
Commercial mortgage-backed securities	35		—		35		—
Corporate debt securities	114		—		114		—
Equity securities	403		403		—		—
Foreign government fixed income securities	1		—		1		—
Other trust fund investments (classified within other non-current assets):
U.S. government and federal agency obligations	1		1		—		—
Derivative assets:
Foreign exchange contracts	18		—		18		—
Commodity contracts	11,976		1,929		8,796		1,251
Measured using net asset value practical expedient:
Equity securities - nuclear trust fund investments	83
Equity securities (classified within other non-current assets)	6
Total assets	$	12,858	$	2,432	$	9,086	$	1,251
Derivative liabilities:
Foreign exchange contracts	$	2	$	—	$	2	$	—
Commodity contracts	8,439		1,244		6,449		746
Total liabilities	$	8,441	$	1,244	$	6,451	$	746

The following table reconciles, for the years ended December 31, 2023 and 2022, the beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs, for commodity derivatives:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Commodity Derivatives (a)
	For the Year Ended December 31,
(In millions)	2023		2022
Beginning balance	$	505	$	293
Total (losses)/gains realized/unrealized included in earnings	(164)		53
Purchases	42		(110)
Transfers into Level 3(b)	78		264
Transfers out of Level 3(b)(c)	(342)		5
Ending balance	$	119	$	505
(Losses)/gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of year-end	$	(46)	$	204

(a)Consists of derivatives assets and liabilities, net, excluding derivative liabilities from Consumer Financing Program, which are presented in a separate table below

(b)Transfers into/out of Level 3 are related to the availability of consensus pricing and external broker quotes, and are valued as of the end of the reporting period. All transfers into/out of Level 3 are from/to Level 2

(c)For the year ended December 31, 2023, due to the change to use consensus pricing, there was a decrease in the number of contracts valued with prices provided by models and other valuation techniques, which resulted in a large transfer out of Level 3

Realized and unrealized gains and losses included in earnings that are related to the commodity derivatives are recorded in revenues and cost of operations.

The following table reconciles, for the year ended December 31, 2023, the beginning and ending balances of the contractual obligations from the Consumer Financing Program that are recognized at fair value in the condensed consolidated financial statements, using significant unobservable inputs:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Consumer Financing Program
(In millions)	For the Year Ended December 31, 2023
Beginning balance	$	—
Contractual obligations added from the acquisition of Vivint Smart Home	(112)
New contractual obligations	(68)
Settlements	62
Total losses included in earnings	(16)
Ending balance	$	(134)

Gains and losses that are related to the Consumer Financing Program derivative are recorded in other income, net.

Non-derivative fair value measurements

For the year ended December 31, 2022 and through the sale of STP on November 1, 2023, the trust fund investments were held primarily to satisfy NRG's nuclear decommissioning obligations. These trust fund investments held debt and equity securities directly and equity securities indirectly through commingled funds. The fair values of equity securities held directly by the trust funds were based on quoted prices in active markets and were categorized in Level 1. In addition, U.S. government and federal agency obligations were categorized as Level 1 because they traded in a highly liquid and transparent market. The fair values of corporate debt securities were based on evaluated prices that reflected observable market information, such as actual trade information of similar securities, adjusted for observable differences and were categorized in Level 2. Certain equity securities, classified as commingled funds, were analogous to mutual funds, were maintained by investment companies, and held certain investments in accordance with a stated set of fund objectives. The fair value of the equity securities classified as commingled funds were based on net asset values per fund share (the unit of account), derived from the quoted prices in active markets of the underlying equity securities. However, because the shares in the commingled funds were not publicly quoted and not traded in an active market, the commingled funds were measured using net asset value practical expedient. See also Note 7, Nuclear Decommissioning Trust Fund.

Derivative fair value measurements

The Company's contracts consist of non-exchange-traded contracts valued using prices provided by external sources and exchange-traded contracts with readily available quoted market prices. Beginning in of the fourth quarter of 2023 and as of December 31, 2023, the fair value of non-exchange traded contracts were based on consensus pricing provided by independent pricing services. The pricing data was compiled from market makers with longer dated tenors as compared to broker quotes, enhancing reliability and increasing transparency.

Prior to the fourth quarter of 2023, the Company valued derivatives based on price quotes from brokers in active markets who regularly facilitate those transactions. For the majority of markets that NRG participates in, the Company would receive broker quotes from multiple sources and reflected the average of the bid-ask mid-point prices. The terms for which such price information is available vary by commodity, region and product. The Company believes both sources of price quotes are executable.

The remainder of the assets and liabilities represents 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 observable market data with similar characteristics. As of December 31, 2023, contracts valued with prices provided by models and other valuation techniques make up 5% of derivative assets and 6% of derivative liabilities. As a result of NRG switching to consensus pricing as of December 31, 2023, there was a significant decrease in the number of contracts valued with prices provided by models and other valuation techniques. The fair value of each contract is discounted using a risk free interest rate. In addition, the Company applies a credit reserve to reflect credit risk, which for foreign exchange contracts and interest rate swaps is calculated utilizing the bilateral method based on published default probabilities. For commodities, to the extent that NRG's net exposure under a specific master agreement is an asset, the Company uses the counterparty's default swap rate. If the exposure under a specific master agreement is a liability, the Company uses NRG's default swap rate. For foreign exchange contracts, 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 NRG's liabilities or that a market participant would be willing to pay for NRG's assets. As of December 31, 2023, the credit reserve resulted in a $18 million decrease primarily within cost of operations. As of December 31, 2022, the credit reserve resulted in $9 million decrease primarily within cost of operations.

The fair values in each category reflect the level of forward prices and volatility factors as of December 31, 2023 and may change as a result of changes in these factors. Management uses its best estimates to determine the fair value of commodity and derivative contracts NRG holds and sells. These estimates consider various factors including closing exchange, consensus and over-the-counter price quotations, time value, volatility factors and credit exposure. It is possible, however, that future market prices could vary from those used in recording assets and liabilities from energy marketing and trading activities and such variations could be material.

NRG's significant positions classified as Level 3 include physical and financial natural gas, power, capacity contracts and renewable energy certificates executed in illiquid markets as well as financial transmission rights ("FTRs"). The significant unobservable inputs used in developing fair value include illiquid natural gas and power location pricing, which is derived as a basis to liquid locations. The basis spread is based on observable market data when available or derived from historic prices and forward market prices from similar observable markets when not available. Forward capacity prices are based on market information, forecasted future electricity demand and supply, past auctions and internally developed pricing models. Renewable energy certificate prices are based on market information and internally developed pricing models. For FTRs, NRG uses the most recent auction prices to derive the fair value. The Consumer Financing Program derivatives are valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates.

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company's Level 3 positions as of December 31, 2023 and 2022:

	Significant Unobservable Inputs
	December 31, 2023
	Fair Value						Input/Range
(in millions, except as noted)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low			High			Weighted Average
Natural Gas Contracts	$	39	$	65	Discounted Cash Flow	Forward Market Price ($ per MMBtu)	$	1		$	15		$	3
Power Contracts	197		66		Discounted Cash Flow	Forward Market Price ($ per MWh)	1			210			47
Capacity Contracts	21		33		Discounted Cash Flow	Forward Market Price ($ per MW/Day)	49			658			285
Renewable Energy Certificates	58		14		Discounted Cash Flow	Forward Market Price ($ per Certificate)	2			320			15
FTRs	19		37		Discounted Cash Flow	Auction Prices ($ per MWh)	(58)			252			0
Consumer Financing Program	—		134		Discounted Cash Flow	Collateral Default Rates	0.43		%	93.30		%	8.12		%
					Discounted Cash Flow	Collateral Prepayment Rates	2.00		%	3.00		%	2.95		%
					Discounted Cash Flow	Credit Loss Rates	6.00		%	60.00		%	12.57		%
	$	334	$	349

	Significant Unobservable Inputs
	December 31, 2022
	Fair Value						Input/Range
(in millions, except as noted)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
Natural Gas Contracts	$	340	$	448	Discounted Cash Flow	Forward Market Price ($ per MMBtu)	$	2	$	48	$	6
Power Contracts	843		216		Discounted Cash Flow	Forward Market Price ($ per MWh)	3		431		48
FTRs	68		82		Discounted Cash Flow	Auction Prices ($ per MWh)	(32)		610		0
	$	1,251	$	746

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2023 and 2022:

Significant Unobservable Input	Position	Change In Input	Impact on Fair Value Measurement
Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates	Buy	Increase/(Decrease)	Higher/(Lower)
Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates	Sell	Increase/(Decrease)	Lower/(Higher)
FTR Prices	Buy	Increase/(Decrease)	Higher/(Lower)
FTR Prices	Sell	Increase/(Decrease)	Lower/(Higher)
Collateral Default Rates	n/a	Increase/(Decrease)	Higher/(Lower)
Collateral Prepayment Rates	n/a	Increase/(Decrease)	Lower/(Higher)
Credit Loss Rates	n/a	Increase/(Decrease)	Higher/(Lower)

Under the guidance of ASC 815, entities may choose to offset cash collateral posted or received against the fair value of derivative positions executed with the same counterparties under the same master netting agreements. The Company has chosen not to offset positions as defined in ASC 815. As of December 31, 2023, the Company recorded $441 million of cash collateral posted and $84 million of cash collateral received on its balance sheet.

Concentration of Credit Risk

In addition to the credit risk discussion as disclosed in Note 2, Summary of Significant Accounting Policies, the following item is a discussion of the concentration of credit risk for the Company's financial instruments. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; (ii) a daily monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties. The Company also has credit protection within various agreements to call on additional collateral support if and when necessary. Cash margin is collected and held at the Company to cover the credit risk of the counterparty until positions settle.

Counterparty Credit Risk

As of December 31, 2023, counterparty credit exposure, excluding credit exposure from RTOs, ISOs, and registered commodity exchanges and certain long-term agreements, was $1.6 billion and NRG held collateral (cash and letters of credit) against those positions of $426 million, resulting in a net exposure of $1.2 billion. NRG periodically receives collateral from counterparties in excess of their exposure. Collateral amounts shown include such excess while net exposure shown excludes excess collateral received. Approximately 63% of the Company's exposure before collateral is expected to roll off by the end of 2025. Counterparty credit exposure is valued through observable market quotes and discounted at a risk free interest rate. The following tables highlight net counterparty credit exposure by industry sector and by counterparty credit quality. Net counterparty credit exposure is defined as the aggregate net asset position for NRG with counterparties where netting is permitted under the enabling agreement and includes all cash flow, mark-to-market and NPNS, and non-derivative transactions. The exposure is shown net of collateral held and includes amounts net of receivables or payables.

Category	Net Exposure (a) (b) (% of Total)
Utilities, energy merchants, marketers and other	80	%
Financial institutions	20
Total	100	%

Category	Net Exposure (a) (b) (% of Total)
Investment grade	44	%
Non-Investment grade/Non-Rated	56
Total	100	%

(a)Counterparty credit exposure excludes coal transportation contracts because of the unavailability of market prices

(b)The figures in the tables above exclude potential counterparty credit exposure related to RTOs, ISOs, registered commodity exchanges and certain long term contracts

The Company currently has exposure to one wholesale counterparty in excess of 10% of the total net exposure discussed above as of December 31, 2023. Changes in hedge positions and market prices will affect credit exposure and counterparty concentration.

RTOs and ISOs

The Company participates in the organized markets of CAISO, ERCOT, AESO, IESO, ISO-NE, MISO, NYISO and PJM, known as RTOs or ISOs. Trading in the majority of these markets is approved by FERC, whereas in the case of ERCOT, it is approved by the PUCT, and whereas in the case of AESO and IESO, both exist provincially with AESO primarily subject to Alberta Utilities Commission and the IESO subject to the Ontario Energy Board. These ISOs may include credit policies that, under certain circumstances, require that losses arising from the default of one member on spot market transactions be shared by the remaining participants. As a result, the counterparty credit risk to these markets is limited to NRG’s share of the overall market and are excluded from the above exposures.

Exchange Traded Transactions

The Company enters into commodity transactions on registered exchanges, notably ICE, NYMEX and Nodal. These clearinghouses act as the counterparty and transactions are subject to extensive collateral and margining requirements. As a result, these commodity transactions have limited counterparty credit risk.

Long-Term Contracts

Counterparty credit exposure described above excludes credit risk exposure under certain long term contracts, primarily solar under Renewable PPAs. As external sources or observable market quotes are not always available to estimate such exposure, the Company values these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. Based on these valuation techniques, as of December 31, 2023, aggregate credit risk exposure managed by NRG to these counterparties was approximately $882 million for the next five years.

Retail Customer Credit Risk

The Company is exposed to retail credit risk through the Company's retail electricity and gas providers, which serve Home and Business customers. Retail credit risk results in losses when a customer fails to pay for services rendered. The losses may result from both nonpayment of customer accounts receivable and the loss of in-the-money forward value. The Company manages retail credit risk through the use of established credit policies that include monitoring of the portfolio and the use of credit mitigation measures such as deposits or prepayment arrangements.

As of December 31, 2023, the Company's retail customer credit exposure to Home and Business customers was diversified across many customers and various industries, as well as government entities. Current economic conditions may affect the Company's customers' ability to pay bills in a timely manner, which could increase customer delinquencies and may lead to an increase in credit losses. The Company's provision for credit losses was $251 million, $11 million, and $698 million for the years ended December 31, 2023, 2022, and 2021, respectively. During the year ended December 31, 2022, the provision for credit losses included the Company's loss mitigation efforts recognized as income of $126 million related to Winter Storm Uri. During the year ended December 31, 2021, the provision for credit losses included $596 million of expenses due to the impacts of Winter Storm Uri.

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Accounting for Derivative Instruments and Hedging Activities

12 Months Ended

Dec. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Accounting for Derivative Instruments and Hedging Activities

Accounting for Derivative Instruments and Hedging Activities

ASC 815 requires the Company to recognize all derivative instruments on the balance sheet as either assets or liabilities and to measure them at fair value each reporting period unless they qualify for a NPNS exception. The Company may elect to designate certain derivatives as cash flow hedges, if certain conditions are met, and defer the change in fair value of the derivatives to accumulated OCI, until the hedged transactions occur and are recognized in earnings.

For derivatives that are not designated as cash flow hedges or do not qualify for hedge accounting treatment, the changes in the fair value will be immediately recognized in earnings. Certain derivative instruments may qualify for the NPNS exception and are therefore exempt from fair value accounting treatment. ASC 815 applies to NRG's energy related commodity contracts, foreign exchange contracts, interest rate swaps and Consumer Financing Program.

As the Company engages principally in the trading and marketing of its generation assets and retail operations, some of NRG's commercial activities qualify for NPNS accounting. Most of the retail load contracts either qualify for the NPNS exception or fail to meet the criteria for a derivative and the majority of the retail supply and fuels supply contracts are recorded under mark-to-market accounting. All of NRG's hedging and trading activities are subject to limits within the Company's Risk Management Policy.

Energy-Related Commodities

To manage the commodity price risk associated with the Company's competitive supply activities and the price risk associated with wholesale power sales from the Company's electric generation facilities and retail power and gas sales from NRG's retail operations, NRG enters into a variety of derivative and non-derivative hedging instruments, utilizing the following:

•Forward contracts, which commit NRG to purchase or sell energy commodities or fuels in the future;

•Futures contracts, which are exchange-traded standardized commitments to purchase or sell a commodity or financial instrument;

•Swap agreements, which require payments to or from counterparties based upon the differential between two prices for a predetermined contractual, or notional, quantity;

•Option contracts, which convey to the option holder the right but not the obligation to purchase or sell a commodity; and

•Weather derivative products used to mitigate a portion of lost revenue due to weather.

The objectives for entering into derivative contracts designated as hedges include:

•Fixing the price of a portion of anticipated power and gas purchases for the Company's retail sales;

•Fixing the price for a portion of anticipated future electricity sales that provides an acceptable return on the Company's electric generation operations; and

•Fixing the price of a portion of anticipated fuel purchases for the operation of the Company's power plants.

These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative financial instruments are recognized in earnings.

As of December 31, 2023, NRG's derivative assets and liabilities consisted primarily of the following:

•Forward and financial contracts for the purchase/sale of electricity and related products economically hedging NRG's generation assets' forecasted output or NRG's retail load obligations through 2036;

•Forward and financial contracts for the purchase of fuel commodities relating to the forecasted usage of NRG's generation assets through 2025;

•Other energy derivatives instruments extending through 2029.

Also, as of December 31, 2023, NRG had other energy-related contracts that did not meet the definition of a derivative instrument or qualified for the NPNS exception and were therefore exempt from fair value accounting treatment as follows:

•Load-following forward electric sale contracts extending through 2036;

•Load-following forward natural gas purchase and sale contracts extending through 2032;

•Power tolling contracts through 2036;

•Coal purchase contracts through 2024;

•Power transmission contracts through 2029;

•Natural gas transportation contracts through 2034;

•Natural gas storage agreements through 2030; and

•Coal transportation contracts through 2029.

Foreign Exchange Contracts

In order to mitigate foreign exchange risk primarily associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements through 2027.

Interest Rate Swaps

NRG is exposed to changes in interest rate through the Company's issuance of variable rate debt. To manage the Company's interest rate risk, NRG enters into interest rate swap agreements. In the first quarter of 2023, the Company entered into $1.0 billion of interest rate swaps through 2027 to hedge the floating rate on the Term Loan acquired with the Vivint Smart Home acquisition. Additionally, in the first quarter of 2023, the Company had entered into interest rate swaps to hedge the floating rate on the Revolving Credit Facility extending through 2024, which was fully terminated in conjunction with the pay down of the Revolving Credit Facility.

Consumer Financing Program

Under the Consumer Financing Program, Vivint Smart Home pays a monthly fee to Financing Providers based on either the average daily outstanding balance of the loans or the number of outstanding loans. For certain loans, Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees. Vivint Smart Home also shares the liability for credit losses, depending on the credit quality of the subscriber. Due to the nature of certain provisions under the Consumer Financing Program, the Company records a derivative liability that is not designated as a hedging instrument and is adjusted to fair value, measured using the present value of the estimated future payments. Changes to the fair value are recorded through other income, net in the consolidated statement of operations. The following represent the contractual future payment obligations with the Financing Providers under the Consumer Financing Program that are components of the derivative:

•    Vivint Smart Home pays either a monthly fee based on the average daily outstanding balance of the loans, or the number of outstanding loans, depending on the Financing Provider;

•    Vivint Smart Home shares the liability for credit losses depending on the credit quality of the subscriber; and

•    Vivint Smart Home pays transactional fees associated with subscriber payment processing.

The derivative is classified as a Level 3 instrument. The derivative positions are valued using a discounted cash flow model, with inputs consisting of available market data, such as market yield discount rates, as well as unobservable internally derived assumptions, such as collateral prepayment rates, collateral default rates and credit loss rates. In summary, the fair value represents an estimate of the present value of the cash flows Vivint Smart Home will be obligated to pay to the Financing Provider for each component of the derivative.

Volumetric Underlying Derivative Transactions

The following table summarizes the net notional volume buy/(sell) of NRG's open derivative transactions broken out by commodity, excluding those derivatives that qualified for the NPNS exception as of December 31, 2023 and 2022. Option contracts are reflected using delta volume. Delta volume equals the notional volume of an option adjusted for the probability that the option will be in-the-money at its expiration date.

		Total Volume (In millions)
Category	Units	December 31, 2023	December 31, 2022
Emissions	Short Ton	—	1
Renewables Energy Certificates	Certificates	12	15
Coal	Short Ton	9	11
Natural Gas	MMBtu	838	422
Oil	Barrels	—	1
Power	MWh	201	192
Interest	Dollars	1,000	—
Foreign Exchange	Dollars	548	569
Consumer Financing Program	Dollars	1,116	—

Fair Value of Derivative Instruments

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

	Fair Value
	Derivative Assets				Derivative Liabilities
(In millions)	December 31, 2023		December 31, 2022		December 31, 2023		December 31, 2022
Derivatives Not Designated as Cash Flow or Fair Value Hedges:
Interest rate contracts - current	$	12	$	—	$	—	$	—
Interest rate contracts - long-term	—		—		8		—
Foreign exchange contracts - current	3		11		4		1
Foreign exchange contracts - long-term	2		7		5		1
Commodity contracts- current	3,847		7,875		3,922		6,194
Commodity contracts- long-term	2,291		4,101		1,434		2,245
Consumer Financing Program - current	—		—		93		—
Consumer Financing Program - long-term	—		—		41		—
Total Derivatives Not Designated as Cash Flow or Fair Value Hedges	$	6,155	$	11,994	$	5,507	$	8,441

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. In addition, collateral received or paid on the Company's derivative assets or liabilities are recorded on a separate line item on the balance sheet. The following table summarizes the offsetting derivatives by counterparty master agreement level and collateral received or paid:

	Gross Amounts Not Offset in the Statement of Financial Position
(In millions)	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Cash Collateral (Held)/Posted		Net Amount
As of December 31, 2023
Interest rate contracts:
Derivative assets	$	12	$	(8)	$	—	$	4
Derivative liabilities	(8)		8		—		—
Total interest rate contracts	4		—		—		4
Foreign exchange contracts:
Derivative assets	$	5	$	(5)	$	—	$	—
Derivative liabilities	(9)		5		—		(4)
Total foreign exchange contracts	$	(4)	$	—	$	—	$	(4)
Commodity contracts:
Derivative assets	$	6,138	$	(4,926)	$	(74)	$	1,138
Derivative liabilities	(5,356)		4,926		145		(285)
Total commodity contracts	$	782	$	—	$	71	$	853
Consumer Financing Program:
Derivative liabilities	$	(134)	$	—	$	—	$	(134)
Total derivative instruments	$	648	$	—	$	71	$	719

	Gross Amounts Not Offset in the Statement of Financial Position
(In millions)	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Cash Collateral (Held)/Posted		Net Amount
As of December 31, 2022
Foreign exchange contracts:
Derivative assets	$	18	$	(2)	$	—	$	16
Derivative liabilities	(2)		2		—		—
Total foreign exchange contracts	$	16	$	—	$	—	$	16
Commodity contracts:
Derivative assets	$	11,976	$	(7,897)	$	(1,659)	$	2,420
Derivative liabilities	(8,439)		7,897		20		(522)
Total commodity contracts	$	3,537	$	—	$	(1,639)	$	1,898
Total derivative instruments	$	3,553	$	—	$	(1,639)	$	1,914

Impact of Derivative Instruments on the Statement of Operations

Unrealized gains and losses associated with changes in the fair value of derivative instruments that are not accounted for as cash flow hedges are reflected in current period results of operations.

The following table summarizes the pre-tax effects of economic hedges that have not been designated as cash flow hedges or fair value hedges and trading activity on the Company's statement of operations. The effect of foreign exchange and commodity hedges is included within revenues and cost of operations. The effect of the interest rate contracts are included within interest expense. The effect of the Consumer Financing Program is included in other income, net.

	Year Ended December 31,
(In millions)	2023		2022		2021
Unrealized mark-to-market results
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$	(1,734)	$	(1,232)	$	(41)
Reversal of acquired loss positions related to economic hedges	20		2		256
Net unrealized (losses)/gains on open positions related to economic hedges	(1,149)		2,478		2,501
Total unrealized mark-to-market (losses)/gains for economic hedging activities	(2,863)		1,248		2,716
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	13		13		(18)
Reversal of acquired (gain) positions related to trading activity	—		—		(1)
Net unrealized gains/(losses) on open positions related to trading activity	25		(17)		(13)
Total unrealized mark-to-market gains/(losses) for trading activity	38		(4)		(32)
Total unrealized (losses)/gains - commodities and foreign exchange	$	(2,825)	$	1,244	$	2,684

	Year Ended December 31,
(In millions)	2023		2022		2021
Total impact to statement of operations - interest rate contracts	$	4	$	—	$	—
Unrealized gains/(losses) included in revenues - commodities	$	182	$	(87)	$	(196)
Unrealized (losses)/gains included in cost of operations - commodities	(2,988)		1,315		2,880
Unrealized (losses)/gains included in cost of operations - foreign exchange	(19)		16		—
Total impact to statement of operations - commodities and foreign exchange	$	(2,825)	$	1,244	$	2,684
Total impact to statement of operations - Consumer Financing Program	$	(16)	$	—	$	—

        

The reversals of acquired loss/(gain) positions were valued based upon the forward prices on the acquisition date. The roll-off amounts were offset by realized gains or losses at the settled prices and are reflected in revenue or cost of operations during the same period.

The loss from open economic hedge positions of $1.1 billion for the year ended December 31, 2023 was primarily the result of a decrease in the value of forward positions as a result of decreases in natural gas and power prices in the East and West.

The gains from open economic hedge positions of $2.5 billion for the years ended December 31, 2022 and 2021 were primarily the result of an increase in value of forward positions as a result of increases in natural gas and power prices.

Credit Risk Related Contingent Features

Certain of the Company's hedging and trading agreements contain provisions that entitle the counterparty to demand that the Company post additional collateral if the counterparty determines that there has been deterioration in the Company's credit quality, generally termed “adequate assurance” under the agreements, or require the Company to post additional collateral if there were a downgrade in the Company's credit rating. The collateral potentially required for contracts with adequate assurance clauses that are in net liability positions as of December 31, 2023 was $600 million. The Company is also a party to certain marginable agreements under which it has a net liability position, but the counterparty has not called for the collateral due, which was approximately $80 million as of December 31, 2023. In the event of a downgrade in the Company's credit rating and

if called for by the counterparty, $8 million of additional collateral would be required for all contracts with credit rating contingent features as of December 31, 2023.

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

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Nuclear Decommissioning Trust Fund

12 Months Ended

Dec. 31, 2023

Regulated Operations [Abstract]

Nuclear Decommissioning Trust Fund

Nuclear Decommissioning Trust Fund

Through the sale of the Company's 44% equity interest in STP on November 1, 2023, NRG's Nuclear Decommissioning Trust Fund assets, which were for the decommissioning of STP, were comprised of securities classified as available-for-sale and recorded at fair value based on actively quoted market prices. NRG accounted for the Nuclear Decommissioning Trust Fund in accordance with ASC 980, Regulated Operations, or ASC 980, because the Company's nuclear decommissioning activities were subject to approval by the PUCT, with regulated rates that are designed to recover all decommissioning costs and that can be charged to and collected from the ratepayers per PUCT mandate. Since the Company was in compliance with PUCT rules and regulations regarding decommissioning trusts and the cost of decommissioning was the responsibility of the Texas ratepayers, not NRG, all realized and unrealized gains or losses (including other-than-temporary impairments) related to the Nuclear Decommissioning Trust Fund were recorded to the Nuclear Decommissioning Trust liability and were not included in net income or accumulated other comprehensive income, consistent with regulatory treatment.

Following the sale of the Company's 44% equity interest in STP on November 1, 2023, the Company is no longer responsible for the decommissioning of STP and no longer holds the Nuclear Decommissioning Trust Fund assets. For further discussion of the sale, see Note 4, Acquisitions and Dispositions.

The following table summarizes the aggregate fair values and unrealized gains and losses for the securities held in the trust funds as of December 31, 2022, as well as information about the contractual maturities of those securities as of that date.

	As of December 31, 2022
(In millions, except otherwise noted)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted- average maturities (in years)
Cash and cash equivalents	$	15	$	—	$	—	—
U.S. government and federal agency obligations	86		—		5		11
Federal agency mortgage-backed securities	101		—		11		26
Commercial mortgage-backed securities	35		—		4		30
Corporate debt securities	114		—		13		12
Equity securities	486		346		3		—
Foreign government fixed income securities	1		—		—		17
Total	$	838	$	346	$	36

The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from these sales for the ten months ended October 31, 2023, and for the years ended December 31, 2022 and 2021. The cost of securities sold was determined using the specific identification method.

(In millions)	2023		2022		2021
Realized gains	$	11	$	14	$	47
Realized losses	(19)		(25)		(9)
Proceeds from sale of securities	355		448		710

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Inventory

12 Months Ended

Dec. 31, 2023

Inventory Disclosure [Abstract]

Inventory

Inventory

Inventory consisted of:

	As of December 31,
(In millions)	2023		2022
Fuel oil	$	8	$	8
Coal	178		114
Natural gas	189		385
Spare parts	68		136
Finished goods	164		108
Total Inventory	$	607	$	751

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Property, Plant and Equipment

12 Months Ended

Dec. 31, 2023

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Property, Plant and Equipment

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

	As of December 31,				Depreciable
(In millions)	2023		2022		Lives
Facilities and equipment	$	1,918	$	1,727	1-40 years
Land and improvements	256		263
Nuclear fuel	—		271		5 years
Hardware and office equipment and furnishings	732		712		2-10 years
Construction in progress	152		197
Total property, plant, and equipment	3,058		3,170
Accumulated depreciation	(1,295)		(1,478)
Net property, plant, and equipment	$	1,763	$	1,692

Depreciation expense of property, plant and equipment recorded during the years ended December 31, 2023, 2022 and 2021 was $257 million, $291 million and $384 million, respectively.

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Leases

12 Months Ended

Dec. 31, 2023

Leases [Abstract]

Leases

Leases

The Company leases generating facilities, land, office and equipment, railcars, fleet vehicles and storefront space at retail stores. Operating leases with an initial term greater than twelve months are recognized as right-of-use assets and lease liabilities in the consolidated balance sheets. The Company made an accounting policy election, as permitted by ASC 842, for all asset classes not to recognize right-of-use assets and lease liabilities in the consolidated balance sheets for its short-term leases, which are leases that have a lease term of twelve months or less. For the initial measurement of lease liabilities, the discount rate that the Company uses is either the rate implicit in the lease, if known, or its incremental borrowing rate, which is the rate of interest that the Company would have to pay to borrow, on a collateralized basis, over a similar term an amount equal to the payments for the lease. The Company recognizes lease expense for all operating leases on a straight-line basis over the lease term. In the future, should another systematic basis become more representative of the pattern in which the lessee expects to consume the remaining economic benefit of the right-of-use asset, the Company will use that basis for lease expense.

The Company considers a contract to be or to contain a lease when both of the following conditions apply: 1) an asset is either explicitly or implicitly identified in the contract and 2) the contract conveys to the Company the right to control the use of the identified asset for a period of time. The Company has the right to control the use of the identified asset when the Company has both the right to obtain substantially all the economic benefits from the use of the identified asset and the right to direct how and for what purpose the identified asset is used throughout the period of use.

Lease payments are typically fixed and payable on a monthly, quarterly, semi-annual or annual basis. Lease payments under certain agreements may escalate over the lease term either by a fixed percentage or a fixed dollar amount. Certain leases may provide for variable lease payments in the form of payments based on unit availability, usage, a percentage of sales from the location under lease, or index-based (e.g., the U.S. Consumer Price Index) adjustments to lease payments. The Company has no leases which contain residual value guarantees provided by the Company as a lessee.

Lease Cost:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Finance lease cost	$	8	$	4	$	4
Amortization of right-of-use assets	7		4		4
Interest on lease liabilities	1		—		—
Operating lease cost	93		85		91
Short-term lease cost	42		7		3
Variable lease cost	91		86		9
Sublease income	(2)		(2)		(2)
Total lease cost	$	232	$	180	$	105

Other information:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	195	$	183	$	102
Financing cash flows from finance leases	7		5		6
Right-of-use assets obtained in exchange for new finance lease liabilities	17		3		16
Right-of-use assets obtained in exchange for new operating lease liabilities	52		28		47

Lease Term and Discount Rate for leases:

	December 31, 2023		December 31, 2022
Finance leases:
Weighted average remaining lease term (in years)	2.9		2.6
Weighted average discount rate	4.87	%	2.82	%
Operating leases:
Weighted average remaining lease term (in years)	3.6		4.3
Weighted average discount rate	6.00	%	5.37	%

As of December 31, 2023, annual payments based on the maturities of the Company's operating leases are expected to be as follows:

	In millions
2024	$	118
2025	86
2026	34
2027	24
2028	17
Thereafter	32
Total undiscounted lease payments	$	311
Less: present value adjustment	(93)
Total discounted lease payments	$	218

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Asset Impairments

12 Months Ended

Dec. 31, 2023

Asset Impairment Charges [Abstract]

Asset Impairments

Asset Impairments

2023 Impairment Losses

During the fourth quarter of 2023, the Company completed its annual budget and analyzed the corresponding impact on estimated cash flows associated with its long-lived assets. The fair value of the assets was determined using an income approach by applying a discounted cash flow methodology to the long-term budget for each facility. The income approach utilized estimates of after-tax cash flows, which were Level 3 fair value measurements, and included key inputs such as forecasted power prices, fuel costs, operating and maintenance costs, plant investment capital expenditures and discount rates.

Gladstone — The Company recorded impairment losses of $102 million on its equity method investment in Gladstone within the West/Services/Other segment as a result of changes in the long-term outlook of the Gladstone facility, prompted by evolving energy policy conditions in Australia and an assessment of the long-term operational landscape of the facility, which concluded with the annual budget process. For further discussion of the Gladstone investment, see Note 17, Investments Accounted for by the Equity Method and Variable Interest Entities.

Other Impairments — The Company additionally recorded impairment losses related to property plant and equipment and leases of $2 million, $4 million and $20 million in the Texas, East and West/Services/Other segments, respectively.

2022 Impairment Losses

Astoria Redevelopment Impairment — During the third quarter of 2022, the Company entered into a purchase and sale agreement for the sale of the land and related assets at the Astoria generating site and the planned withdrawal and cancellation of its proposed Astoria redevelopment project. As a result, the Company impaired $43 million of Astoria project spend in the East segment. For further discussion of the transaction, see Note 4, Acquisitions and Dispositions.

PJM Asset Impairments — During the second quarter of 2022, the results of the PJM Base Residual Auction for the 2023/2024 delivery year were released leading the Company to revise its long-term view of certain facilities and announce the planned retirement of the Joliet generating facility. The Company considered the near-term retirement date of Joliet and the decline in PJM capacity prices to be a trigger for impairment and performed impairment tests on the PJM generating assets and the goodwill associated with Midwest Generation. The Company measured the impairment losses on the PJM generating assets and Midwest Generation goodwill as the difference between the carrying amount and the fair value of the PJM generating assets and Midwest Generation reporting unit, respectively. Fair values were determined using an income approach in which the Company applied a discounted cash flow methodology to the long-term budgets for the plants and reporting unit. Significant inputs impacting the income approach include the Company's long-term view of capacity and fuel prices, projected generation, the physical and economic characteristics of each plant and the reporting unit as a whole, and the discount rate applied to the after-tax cash flow projections. Impairment losses of $20 million and $130 million were recorded in the East segment on the PJM generating assets and Midwest Generation goodwill, respectively.

Other Impairments — The Company additionally recorded impairment losses of $13 million in the East segment.

2021 Impairment Losses

During the fourth quarter of 2021, the Company completed its annual budget and analyzed the corresponding impact on estimated cash flows associated with its long-lived assets. The fair value of the assets was determined using an income approach by applying a discounted cash flow methodology to the long-term budget for the facility. The income approach utilized estimates of after-tax cash flows, which were Level 3 fair value measurements, and included key inputs such as forecasted power prices, fuel costs, operating and maintenance costs, plant investment capital expenditures and discount rates.

Joliet —The Company recognized an impairment loss of $213 million in the East segment as a result of changes in the long-term outlook of the Joliet facility prompted by market conditions and an assessment of various alternatives for the long-term operational landscape of the facility including the impact of the CEJA in Illinois, which concluded with the annual budget process.

Other Impairments — The Company additionally recorded impairment losses of $16 million and $9 million related to various power plants in the East and West/Service/Other segments, respectively.

The Company also recorded the following impairment in 2021 based on a specific triggering event that occurred using the same methodology previously discussed:

PJM Asset Impairments — During the second quarter of 2021, the results of the PJM Base Residual Auction for the 2022/2023 delivery year were released leading the Company to announce the near-term retirement of a significant portion of its PJM coal generating assets in June 2022. The Company considered the decline in PJM capacity prices and the near-term retirement dates of certain assets to be a trigger for impairment and performed impairment tests on the PJM generating assets and the goodwill associated with Midwest Generation. Impairment losses of $271 million and $35 million were recorded in the East segment on the PJM generating assets and Midwest Generation goodwill, respectively.

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Goodwill and Other Intangibles

12 Months Ended

Dec. 31, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangibles

Goodwill and Other Intangibles

Goodwill

The table below presents the changes of goodwill for the years ended December 31, 2023 and 2022 based on the Company's reportable segments.

(in millions)	Texas		East		West/Services/Other		Vivint Smart Home		Total
Balance as of January 1, 2022	$	716	$	853	$	226	$	—	$	1,795
Impairment losses	—		(130)		—		—		(130)
Asset sales	(6)		—		—		—		(6)
Foreign currency translation	—		—		(9)		—		(9)
Balance as of December 31, 2022	$	710	$	723	$	217	$	—	$	1,650
Goodwill resulted from the acquisition of Vivint	—		—		—		3,494		3,494
Asset sales	(67)		(2)		—		—		(69)
Foreign currency translation	—		—		4		—		4
Balance as of December 31, 2023	$	643	$	721	$	221	$	3,494	$	5,079

Intangible Assets

The Company's intangible assets as of December 31, 2023, primarily reflect intangible assets established with the acquisitions of various companies, including Vivint Smart Home, Direct Energy, Stream Energy, other retail acquisitions and Texas Genco. Intangible assets are comprised of the following:

•Emission Allowances — These intangibles primarily consist of SO2 emission allowances, including those established with the 2006 acquisition of Texas Genco, RGGI emission credits and California carbon allowances. These emission allowances are held-for-use and are amortized to cost of operations based on units of production.

•Customer and supply contracts — These intangibles include the fair value at the acquisition date of in-market and out-of-market customer and supply contracts from the acquisition of Direct Energy and are amortized to revenue and cost of operations, respectively, based upon the fair market value, as of the acquisition date, for each delivery month.

•Customer relationships — These intangibles represent the fair value at the acquisition date of acquired businesses' customer base from the acquisition of Vivint, Direct Energy and other acquisitions. Customer relationships are amortized to depreciation and amortization expense based on the expected discounted future net cash flows by year.

•Marketing partnerships — These intangibles represent the fair value at the acquisition date of existing agreements with marketing vendors and loyalty and affinity partners for customer acquisition. Marketing partnerships are amortized to depreciation and amortization expense based on the expected discounted future net cash flows by year.

•Technology — These intangibles represent the fair value at the acquisition date of developed technology for Vivint Smart Home integrated software and products. Technology is amortized to depreciation and amortization expense, ratably based on the expected discounted future net cash flows by year.

•Trade names — These intangibles are amortized to depreciation and amortization expense on a straight-line basis.

•Other — These intangibles primarily include renewable energy credits. RECs are retired, as required, for the applicable compliance period. RECs are expensed to cost of operations based on NRG’s customer usage. Other also included in-market nuclear fuel contracts established from the Texas Genco acquisition in 2006 which were amortized to cost of operations over expected volumes over the life of each contract, costs to extend the operating license for STP Units 1 and 2 and intellectual property related to Goal Zero, which is amortized to depreciation and amortization expense.

The following tables summarize the components of NRG's intangible assets:

(In millions)
Year Ended December 31, 2023	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Technology		Trade Names		Other(a)		Total
January 1, 2023	$	624	$	635	$	1,730	$	284	$	—	$	679	$	292	$	4,244
Purchases	10		—		—		—		—		—		465		475
Acquisition of businesses(b)	—		—		1,773		10		860		160		—		2,803
Usage/Sales/Retirements	—		—		—		—		—		—		(474)		(474)
Write-off of fully amortized balances	(1)		(28)		(43)		—		—		—		—		(72)
Sale of STP(c)	—		—		—		—		—		—		(59)		(59)
Other	(5)		2		4		1		—		2		—		4
December 31, 2023	628		609		3,464		295		860		841		224		6,921
Less accumulated amortization	(533)		(328)		(1,300)		(170)		(230)		(401)		(32)		(2,994)
Net carrying amount	$	95	$	281	$	2,164	$	125	$	630	$	440	$	192	$	3,927

(a)RECs are not subject to amortization and had a carrying value of $177 million

(b)The weighted average amortization period for total amortizable intangible assets is approximately 10 years. See Note 4, Acquisitions and Dispositions, for weighted average life of acquired amortizable intangibles for each intangible asset type

(c)Includes $47 million of intangibles that were amortized

(In millions)
Year Ended December 31, 2022	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other(a)		Total
January 1, 2022	$	634	$	638	$	1,679	$	284	$	683	$	229	$	4,147
Purchases	26		—		—		—		—		404		430
Acquisition of businesses(b)	—		—		55		—		—		—		55
Usage/Retirements	(33)		—		—		—		—		(341)		(374)
Write-off of fully amortized balances	(14)		—		—		—		—		—		(14)
Other	11		(3)		(4)		—		(4)		—		—
December 31, 2022	624		635		1,730		284		679		292		4,244
Less accumulated amortization	(528)		(235)		(787)		(146)		(341)		(75)		(2,112)
Net carrying amount	$	96	$	400	$	943	$	138	$	338	$	217	$	2,132

(a)RECs are not subject to amortization and had a carrying value of $186 million

(b)The weighted average life of acquired amortizable intangibles was six years for customer relationships

The following table presents NRG's amortization of intangible assets for each of the past three years:

	Years Ended December 31,
(In millions)	2023		2022		2021
Emission allowances	$	6	$	6	$	24
Customer and supply contracts	121		141		66
Customer relationships	556		269		327
Marketing partnerships	24		23		24
Technology	230		—		—
Trade names	60		47		47
Other(a)	4		4		7
Total amortization	$	1,001	$	490	$	495

(a)For the year ended December 31, 2023, 2022 and 2021, other intangibles amortized to depreciation and amortization expense were de minimis, $4 million and $3 million, respectively

The following table presents estimated amortization of NRG's intangible assets as of December 31, 2023 for each of the next five years:

(In millions)
Year Ended December 31,	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Technology		Trade Names		Other		Total
2024	$	17	$	73	$	478	$	24	$	227	$	54	$	3	$	876
2025	14		50		371		23		176		47		3		684
2026	9		52		300		23		130		39		3		556
2027	8		30		233		23		89		39		3		425
2028	9		13		189		15		9		39		2		276

Intangible assets held-for-sale — From time to time, management may authorize the transfer from the Company's emission bank of emission allowances held-for-use to intangible assets held-for-sale. Emission allowances held-for-sale are included in other non-current assets on the Company's consolidated balance sheet and are not amortized, but rather expensed as sold. As of December 31, 2023 and 2022, the value of emission allowances held-for-sale was $4 million and $8 million, respectively, within the Corporate segment. Once transferred to held-for-sale, these emission allowances are prohibited from moving back to held-for-use.

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Long-term Debt and Finance Leases

12 Months Ended

Dec. 31, 2023

Debt Disclosure [Abstract]

Long-term Debt and Finance Leases

Long-term Debt and Finance Leases

Long-term debt and finance leases consisted of the following:

	As of December 31,
(In millions, except rates)	2023		2022		Interest rate %
Recourse debt:
Senior Notes, due 2027	$	375	$	375	6.625
Senior Notes, due 2028	821		821		5.750
Senior Notes, due 2029	733		733		5.250
Senior Notes, due 2029	500		500		3.375
Senior Notes, due 2031	1,030		1,030		3.625
Senior Notes, due 2032	480		1,100		3.875
Convertible Senior Notes, due 2048(a)	575		575		2.750
Senior Secured First Lien Notes, due 2024	600		600		3.750
Senior Secured First Lien Notes, due 2025	500		500		2.000
Senior Secured First Lien Notes, due 2027	900		900		2.450
Senior Secured First Lien Notes, due 2029	500		500		4.450
Senior Secured First Lien Notes, due 2033	740		—		7.000
Tax-exempt bonds	466		466		1.250 - 4.750
Subtotal recourse debt	8,220		8,100
Non-recourse debt:
Vivint Smart Home Senior Notes, due 2029	800		—		5.750
Vivint Smart Home Senior Secured Notes, due 2027	600		—		6.750
Vivint Smart Home Senior Secured Term Loan, due 2028	1,320		—		SOFR + 3.51
Subtotal all non-recourse debt	2,720		—
Subtotal long-term debt (including current maturities)	10,940		8,100
Finance leases	19		11		various
Subtotal long-term debt and finance leases (including current maturities)	10,959		8,111
Less current maturities	(620)		(63)
Less debt issuance costs	(60)		(70)
Discounts	(146)		(2)
Total long-term debt and finance leases	$	10,133	$	7,976

(a)As of the ex-dividend date of January 31, 2024, the Convertible Senior Notes were convertible at a price of $41.53, which is equivalent to a conversion rate of approximately 24.0763 shares of common stock per $1,000 principal amount

Debt includes the following discounts:

	As of December 31,
(In millions)	2023		2022
Senior Secured First Lien Notes, due 2024, 2025, 2027, 2029 and 2033	$	(10)	$	(2)
Vivint Smart Home Senior Notes, due 2029	(103)		—
Vivint Smart Home Senior Secured Notes, due 2027	(12)		—
Vivint Smart Home Senior Secured Term Loan, due 2028	(21)		—
Total discounts	$	(146)	$	(2)

Consolidated Annual Maturities

As of December 31, 2023, annual payments based on the maturities of NRG's debt and finance leases are expected to be as follows:

	(In millions)
2024	$	620
2025	769
2026	16
2027	1,890
2028	2,145
Thereafter	5,519
Total	$	10,959

Recourse Debt

Revolving Credit Facility

On February 14, 2023 (the “Revolving Credit Facility Sixth Amendment Effective Date”), the Company amended its Revolving Credit Facility to: (i) increase the existing revolving commitments thereunder by $600 million (the “Initial Incremental Commitment”), (ii) extend the maturity date of a portion of the revolving commitments thereunder to February 14, 2028, (iii) transition the benchmark rate applicable to revolving loans from LIBOR to SOFR and (iv) make certain other amendments to the terms of the Revolving Credit Facility for purposes of, among other things, providing additional flexibility.

On March 13, 2023 (the “Revolving Credit Facility Seventh Amendment Effective Date”), the Company further amended its Revolving Credit Facility to increase the existing revolving commitments by an additional $45 million (together with the Initial Incremental Commitment, the "Incremental Commitment").

After giving effect to the Incremental Commitment, the Company had a total of $4.305 billion of revolving commitments available under the Revolving Credit Facility. The full amount of the Initial Incremental Commitment was made available from and after the Revolving Credit Facility Sixth Amendment Effective Date and the full amount of the Incremental Commitment was made available from and after the Revolving Credit Facility Seventh Amendment Effective Date. A portion of the non-extended revolving commitments terminated on July 5, 2023, with the remaining portion thereof terminating on May 28, 2024, unless otherwise extended.

The Revolving Credit Facility is guaranteed by NRG’s existing and future direct and indirect subsidiaries, with customary and agreed-upon exceptions for, among other exceptions, unrestricted subsidiaries, foreign subsidiaries, project subsidiaries, immaterial subsidiaries, captive insurance subsidiaries and securitization vehicles. The Revolving Credit Facility is also secured by a first priority (subject to certain customary permitted liens) perfected security interest in a substantial portion of the property and assets owned by NRG and its subsidiaries that are guarantors under the Revolving Credit Facility, subject to certain exceptions that include, among other things, the capital stock of certain specified subsidiaries, including unrestricted subsidiaries and certain excluded subsidiaries, equity interests in excess of 66% of the total outstanding voting equity interests of certain foreign subsidiaries, equity interests the pledge of which is prohibited by applicable agreements binding on such subsidiaries and other assets that may be designated by NRG as excluded from the collateral that, when taken together with all other assets so designated since the Revolving Credit Facility Sixth Amendment Effective Date, have an aggregate fair market value not exceeding $750 million. The Revolving Credit Facility is secured on a pari passu basis with certain interest rate, foreign currency and commodity hedging obligations of NRG, the Senior Secured First Lien Notes and certain other indebtedness. The collateral securing the Revolving Credit Facility will be released at the Company's request if both the senior unsecured long-term debt securities of the Company and the revolving loans under the Revolving Credit Facility are rated investment grade by any two of the three rating agencies and the satisfaction of certain other conditions, subject to reversion if such rating agencies withdraw such investment grade rating or downgrade such rating below investment grade (or, with respect to the revolving loans, crease to publish a rating).

The Revolving Credit Facility contains customary covenants, which, among other things, require NRG to maintain a maximum first lien leverage ratio on a consolidated basis when amounts outstanding under the Revolving Credit Facility (subject to certain exceptions) exceed a certain threshold and limit, subject to certain exceptions, NRG’s ability to:

•incur indebtedness and liens and enter into sale and lease-back transactions;

•make investments, loans and advances;

•return capital to shareholders;

•repay material subordinated indebtedness;

•consummate mergers, consolidations and asset sales;

•enter into affiliate transactions; and

•change its fiscal year-end.

As of December 31, 2023, there were no outstanding borrowings and there were $883 million in letters of credit issued under the Revolving Credit Facility.

Senior Notes

Issuance of 2033 Senior Secured First Lien Notes

On March 9, 2023, the Company issued $740 million of aggregate principal amount of 7.000% senior secured first lien notes due 2033 (the "2033 Senior Secured First Lien Notes"). The 2033 Senior Secured First Lien Notes are senior secured obligations of NRG and are guaranteed by certain of its subsidiaries that guarantee indebtedness under the Revolving Credit Facility. The 2033 Senior Secured First Lien Notes are secured by a first priority security interest in the same collateral that is pledged for the benefit of the lenders under the Revolving Credit Facility, which collateral consists of a substantial portion of the property and assets owned by the Company and the guarantors. The collateral securing the 2033 Senior Secured First Lien Notes will be released at the Company’s request if the senior unsecured long-term debt securities of the Company are rated investment grade by any two of the three rating agencies and the satisfaction of certain other conditions, subject to reversion if such rating agencies withdraw such investment grade rating or downgrade such rating below investment grade. Interest is paid semi-annually beginning on September 15, 2023 until the maturity date of March 15, 2033. The proceeds of the 2033 Senior Secured First Lien Notes, along with cash on hand and proceeds from certain other financings, were used to fund the acquisition of Vivint Smart Home.

Senior Note Redemptions

During the year ended December 31, 2023, the Company redeemed $620 million in aggregate principal amount of its 3.875% Senior Notes, due 2032, for $509 million, which included the payment of $7 million of accrued interest, using cash on hand at an average early redemption percentage of 81%. In connection with the redemption, a $109 million gain on debt extinguishment was recorded, which included the write-off of previously deferred financing costs and other fees of $9 million.

During the year ended December 31, 2021, the Company redeemed approximately $1.9 billion in aggregate principal amount of its Senior Notes for $1.9 billion using the proceeds of the 2032 Senior Notes and cash on hand, as detailed in the table below. In connection with the redemptions, a $77 million loss on debt extinguishment was recorded, which included the write-off of previously deferred financing costs of $12 million.

(In millions, except percentages)	Principal Repurchased		Cash Paid(a)		Average Early Redemption Percentage
7.250% Senior Notes, due 2026	$	1,000	$	1,056	103.625	%
6.625% Senior Notes, due 2027	855		893		103.313	%
Total	$	1,855	$	1,949

(a)Includes accrued interest of $29 million for redemptions for the year ended December 31, 2021

2048 Convertible Senior Notes

Accounting for Convertible Senior Notes — Upon issuance in 2018, the Convertible Senior Notes were separated into liability and equity components for accounting purposes. The carrying amount of the liability component was initially calculated by measuring the fair value of similar liabilities that do not have an associated convertible feature. The carrying amount of the equity component representing the conversion option was determined by deducting the fair value of the liability component from the par value of the Convertible Senior Notes. This difference represented the debt discount that was amortized to interest expense over seven years, which was determined to be the expected life of the Convertible Senior Notes, using the effective interest rate method. The equity component was recorded in additional paid-in capital and was not remeasured as it continued to meet the conditions for equity classification.

Following the adoption of ASU 2020-06 as of January 1, 2022, the Company no longer records the conversion feature of its convertible senior notes in equity. Instead, the Company combined the previously separated equity component with the liability component, which together is now classified as debt, thereby eliminating the subsequent amortization of the debt discount as interest expense. As a result of the provisions of the amended guidance, the Company recorded a $100 million decrease to additional paid-in capital, a $57 million decrease to debt discount, a $57 million increase to retained earnings, and a $14 million decrease to long-term deferred tax liabilities.

Modification to Convertible Senior Notes — On February 22, 2022, the Company irrevocably elected to eliminate the right to settle conversions only in shares of the Company's common stock, such that any conversion after such date, the Company will pay cash per $1,000 principal amount and will settle in cash or a combination of cash and the Company's common stock for the remainder, if any, of the Company’s conversion obligation in excess of the aggregate principal amount.

Convertible Senior Notes Features — As of December 31, 2023, the Convertible Senior Notes were convertible, under certain circumstances, into cash or a combination of cash and the Company’s common stock at a price of $41.83 per common share, which is equivalent to a conversion rate of approximately 23.9079 shares of common stock per $1,000 principal amount of Convertible Senior Notes. As of December 31, 2022, the Convertible Senior Notes were convertible at a price of $43.46 per common share, which is equivalent to a conversion rate of approximately 23.0116 shares of common stock per $1,000 principal amount of Convertible Senior Notes. The net carrying amounts of the Convertible Senior Notes as of December 31, 2023 and December 31, 2022 were $572 million and $570 million, respectively. The Convertible Senior Notes mature on June 1, 2048, unless earlier repurchased, redeemed or converted in accordance with their terms. The Convertible Senior Notes are convertible at the option of the holders under certain circumstances. Prior to the close of business on the business day immediately preceding December 1, 2024, the Convertible Senior Notes will be convertible only upon the occurrence of certain events and during certain periods, including, among others, during any calendar quarter (and only during such calendar quarter) if the last reported sales price per share of the Company's common stock exceeds 130% of the conversion price for each of at least 20 trading days, whether or not consecutive, during the 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter. Thereafter during specified periods as follows:

•from December 1, 2024 until the close of business on the second scheduled trading day immediately before June 1, 2025; and

•from December 1, 2047 until the close of business on the second scheduled trading day immediately before the maturity date

All conversions with a conversion date that occurs within the specific periods above will be settled after such period pursuant to the terms of the indenture. The following table details the interest expense recorded in connection with the Convertible Senior Notes, due 2048:

	For the years ended December 31,
($ In millions)	2023			2022			2021
Contractual interest expense	$	16		$	16		$	16
Amortization of discount and deferred finance costs(a)	2			1			15
Total	$	18		$	17		$	31
Effective Interest Rate	3.18		%	3.01		%	5.34		%

(a)Upon adoption of ASU 2020-06 on January 1, 2022, which resulted in the removal of the debt discount, no further debt discount amortization is being recorded

Senior Notes Early Redemption

As of December 31, 2023, NRG had the following outstanding issuances of senior notes with an early redemption feature, or Senior Notes:

i.6.625% senior notes, issued August 2, 2016 and due January 15, 2027, or the 2027 Senior Notes;

ii.5.750% senior notes, issued December 7, 2017 and due January 15, 2028, or the 2028 Senior Notes;

iii.5.250% senior notes, issued May 24, 2019 and due June 15, 2029, or the 2029 Senior Notes;

iv.3.375% senior notes, issued December 2, 2020 and due February 15, 2029, or the 3.375% 2029 Senior Notes;

v.3.625% senior notes, issued December 2, 2020 and due February 15, 2031, or the 2031 Senior Notes; and

vi.3.875% senior notes, issued August 23, 2021 and due February 15, 2032, or the 2032 Senior Notes.

The indentures and the forms of notes provide, among other things, that the Senior Notes will be senior unsecured obligations of the Company. The indentures also provide for customary events of default, which include, among others: nonpayment of principal or interest; breach of other agreements in the indentures; defaults in failure to pay certain other indebtedness; the rendering of judgments to pay certain amounts of money against the Company and its subsidiaries; the failure of certain guarantees to be enforceable; and certain events of bankruptcy or insolvency. Generally, if an event of default occurs, the trustee or the holders of at least 25% or 30% (depending on the series of Senior Notes) in principal amount of the then outstanding series of Senior Notes may declare all of the Senior Notes of such series to be due and payable immediately. The terms of the indentures, among other things, limit the Company's ability and certain of its subsidiaries' ability to return capital to stockholders, grant liens on assets to lenders and incur additional debt. Interest is payable semi-annually on the Senior Notes until their maturity dates.

2027 Senior Notes

The Company may redeem some or all of the 2027 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
July 15, 2023 to July 14, 2024	101.104	%
July 15, 2024 and thereafter	100.000	%

2028 Senior Notes

The Company may redeem some or all of the 2028 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
January 15, 2024 to January 14, 2025	101.917	%
January 15, 2025 to January 14, 2026	100.958	%
January 15, 2026 and thereafter	100.000	%

5.250% 2029 Senior Notes

At any time prior to June 15, 2024, the Company may redeem all or a part of the 5.250% 2029 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the notes; or (ii) the excess of the principal amount of the note over the following: the present value of 102.625% of the note, plus interest payments due on the note through June 15, 2024 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the principal amount of the note. In addition, on or after June 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
June 15, 2024 to June 14, 2025	102.625	%
June 15, 2025 to June 14, 2026	101.750	%
June 15, 2026 to June 14, 2027	100.875	%
June 15, 2027 and thereafter	100.000	%

3.375% 2029 Senior Notes

On or after February 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 to February 14, 2026	100.844	%
February 15, 2026 and thereafter	100.000	%

2031 Senior Notes

At any time prior to February 15, 2026, the Company may redeem all or a part of the 2031 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the note; or (ii) the excess of the present value of 101.813% of the note, plus interest payments due on the note through February 15, 2026 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the principal amount of the note. In addition, on or after February 15, 2026, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2026 to February 14, 2027	101.813	%
February 15, 2027 to February 14, 2028	101.208	%
February 15, 2028 to February 14, 2029	100.604	%
February 15, 2029 and thereafter	100.000	%

2032 Senior Notes

At any time prior to August 15, 2024, the Company may redeem up to 40% of the aggregate principal amount of the 2032 Senior Notes, at a redemption price equal to 103.875% of the principal amount of the notes redeemed, plus accrued and unpaid interest, with an amount equal to the net cash proceeds of certain equity offerings, provided that at least 50% of the aggregate principal amount remains outstanding immediately after the occurrence of such redemption. At any time prior to February 15, 2027, the Company may redeem all or a part of the 2032 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the notes; or (ii) the excess of (A) the present value of (1) the redemption price of the note at February 15, 2027 (such redemption price being set forth in the table appearing below in the column “Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)” unless the Sustainability Performance Target has been satisfied in respect of the year ended December 31, 2025 and the Company has provided confirmation thereof to the trustee together with a related confirmation by the External Verifier by the date that is at least 15 days prior to August 15, 2026 in which case the redemption price shall be as set forth in the column “Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)”) plus (2) interest payments due on the note through February 15, 2027 (excluding accrued but unpaid interest to the redemption date) computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50%, over (B) the principal amount of the note. In addition, on or after February 15, 2027, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table during the twelve-month period beginning on February 15 of the years indicated below, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Year	Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)		Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)
2027	101.938	%	102.188	%
2028	101.292	%	101.458	%
2029	100.646	%	100.729	%
2030 and thereafter	100.000	%	100.000	%

Receivables Facility

In 2020, NRG Receivables LLC, a bankruptcy remote, special purpose, indirect wholly owned subsidiary, ("NRG Receivables") entered into the Receivables Facility, subject to adjustments on a seasonal basis, with issuers of asset-backed commercial paper and commercial banks (the "Lenders"). The assets of NRG Receivables are first available to satisfy the claims of the Lenders before making payments on the subordinated note and equity issued by NRG Receivables. The assets of NRG Receivables are not available to the Company and its subsidiaries or creditors unless and until distributed by NRG Receivables. Under the Receivables Facility, certain indirect subsidiaries of the Company sell their accounts receivables to NRG Receivables, subject to certain terms and conditions. In turn, NRG Receivables grants a security interest in the purchased receivables to the Lenders as collateral for cash borrowings and issuances of letters of credit. Pursuant to the Performance Guaranty, the Company has guaranteed, for the benefit of NRG Receivables and the Lenders, the payment and performance by each indirect subsidiary of its respective obligations under the Receivables Facility. The accounts receivables remain on the

Company's consolidated balance sheet and any amounts funded by the Lenders to NRG Receivables will be reflected as short-term borrowings. Cash flows from the Receivables Facility are reflected as financing activities in the Company's consolidated statements of cash flows. The Company continues to service the accounts receivables sold in exchange for a servicing fee.

On June 22, 2023, NRG Receivables amended its existing Receivables Facility to, among other things, (i) extend the scheduled termination date to June 21, 2024, (ii) increase the aggregate commitments from $1.0 billion to $1.4 billion (adjusted seasonally) and (iii) add a new originator. On October 6, 2023, the Receivables Facility was further amended to replace the benchmark interest rate of the Receivable Facility's subordinated note from LIBOR to SOFR. The weighted average interest rate related to usage under the Receivables Facility as of December 31, 2023 was 0.841%. As of December 31, 2023, there were no outstanding borrowings and there were $1.0 billion in letters of credit issued under the Receivables Facility.

Repurchase Facility

In 2020, the Company entered into the Repurchase Facility related to the Receivables Facility. Under the Repurchase Facility, the Company can currently borrow up to $150 million, collateralized by a subordinated note issued by NRG Receivables to NRG Retail LLC in favor of the originating entities representing a portion of the balance of receivables sold to NRG Receivables under the Receivables Facility.

In addition, in connection with the amendments to the Receivables Facility, on June 22, 2023, the Company and the originators thereunder renewed the existing uncommitted Repurchase Facility. Such renewal, among other things, extended the maturity date to June 21, 2024 and joined an additional originator to the Repurchase Facility. On October 6, 2023, the Repurchase Facility was further amended to reflect the concurrent amendment to the Receivables Facility's subordinated note. The Repurchase Facility has no commitment fee and borrowings will be drawn at SOFR + 1.55%. As of December 31, 2023, there were no outstanding borrowings under the Repurchase Facility.

Bilateral Letter of Credit Facilities

On May 19, 2023, May 30, 2023 and October 17, 2023 the Company increased the size of its bilateral letter of credit facilities by $25 million, $100 million and $50 million, respectively, to provide additional liquidity and to allow for the issuance of up to $850 million of letters of credit. These facilities are uncommitted. As of December 31, 2023, $671 million was issued under these facilities.

Tax Exempt Bonds

	As of December 31,
(In millions, except rates)	2023		2022		Interest Rate %
NRG Indian River Power 2020, tax exempt bonds, due 2040	$	57	$	57	1.250
NRG Indian River Power 2020, tax exempt bonds, due 2045	190		190		1.250
NRG Dunkirk 2020, tax exempt bonds, due 2042	59		59		4.250
City of Texas City, tax exempt bonds, due 2045	33		33		4.125
Fort Bend County, tax exempt bonds, due 2038	54		54		4.750
Fort Bend County, tax exempt bonds, due 2042	73		73		4.750
Total	$	466	$	466

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2023

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

The Company's AROs are primarily related to the environmental obligations for mine reclamation, ash disposal, site closures, fuel storage facilities and future dismantlement of equipment on leased property. In addition, the Company has also identified conditional AROs for asbestos removal and disposal, which are specific to certain power generation operations.

Following the sale of the Company's 44% equity interest in STP on November 1, 2023, the Company no longer has asset retirement obligations related to nuclear decommissioning. Prior to the sale, accretion for the nuclear decommissioning ARO and amortization of the related ARO asset were recorded to the Nuclear Decommissioning Trust Liability and were not included in net income, consistent with regulatory treatment per ASC 980, Regulated Operations.

The following table represents the balance of ARO obligations as of December 31, 2023 and 2022, along with the activity related to the Company's ARO obligations for the year ended December 31, 2023:

(In millions)	Nuclear Decommission		Other(a)		Total
Balance as of December 31, 2022	$	340	$	418	$	758
Revisions in estimates for current obligations	(13)		3		(10)
Additions	—		13		13
Spending for current obligations	—		(42)		(42)
Accretion	16		23		39
Dispositions	(343)		(8)		(351)
Balance as of December 31, 2023	$	—	$	407	$	407

(a)Total accretion expense related to asset retirement obligations included in the consolidated statement of cash flows includes accretion and revisions in estimates for asset retirement liabilities on non-operating plants

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Benefit Plans and Other Postretirement Benefits

12 Months Ended

Dec. 31, 2023

Retirement Benefits [Abstract]

Benefit Plans and Other Postretirement Benefits

Benefit Plans and Other Postretirement Benefits

NRG sponsors and operates defined benefit pension and other postretirement plans. NRG pension benefits are available to eligible non-union and union employees through various defined benefit pension plans. These benefits are based on pay, service history and age at retirement. Most pension benefits are provided through tax-qualified plans. NRG also provides postretirement health and welfare benefits for certain groups of employees. Cost sharing provisions vary by the terms of any applicable collective bargaining agreements.

NRG maintains three separate qualified pension plans, the NRG Pension Plan for Bargained Employees, the NRG Pension Plan and the Pension Plan for Employees of Direct Energy Marketing Limited ("DEML"). Participation in the NRG Pension Plan for Bargained Employees depends upon whether an employee is covered by a bargaining agreement. The NRG Pension plan was frozen for non-union employees on December 31, 2018. The Pension Plan for Employees of DEML is closed to new participants.

NRG expects to contribute $43 million to the Company's pension plans in 2024, of which $23 million relates to the GenOn plan.

NRG Defined Benefit Plans

The annual net periodic benefit cost/(credit) related to NRG's pension and other postretirement benefit plans include the following components:

	Year Ended December 31,
	Pension Benefits
(In millions)	2023		2022		2021
Service cost benefits earned	$	5	$	7	$	9
Interest cost on benefit obligation	50		41		27
Expected return on plan assets	(39)		(47)		(66)
Amortization of unrecognized net loss	6		3		1
Curtailment and special termination benefits (income)/expense	(1)		14		2
Net periodic benefit cost/(credit)	$	21	$	18	$	(27)

	Year Ended December 31,
	Other Postretirement Benefits
(In millions)	2023		2022		2021
Interest cost on benefit obligation	$	4	$	2	$	2
Amortization of unrecognized prior service cost	(8)		(8)		(10)
Amortization of unrecognized net loss	1		2		1
Curtailment expense	—		—		1
Net periodic benefit credit	$	(3)	$	(4)	$	(6)

A comparison of the pension benefit obligation, other postretirement benefit obligations and related plan assets for NRG's plans on a combined basis is as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Benefit obligation at January 1	$	1,036	$	1,452	$	84	$	105
Service cost	5		7		—		—
Interest cost	50		41		4		2
Actuarial loss/(gain)	22		(289)		(5)		(11)
Employee and retiree contributions	—		—		4		3
Curtailment and special termination benefit loss	(2)		—		(1)		—
Benefit payments	(89)		(171)		(11)		(15)
Foreign exchange translation	1		(4)		—		—
Benefit obligation at December 31	1,023		1,036		75		84
Fair value of plan assets at January 1	844		1,336		—		—
Actual return on plan assets	93		(317)		—		—
Employee and retiree contributions	—		—		4		3
Employer contributions	2		—		7		12
Benefit payments	(89)		(171)		(11)		(15)
Foreign exchange translation	1		(4)		—		—
Fair value of plan assets at December 31	851		844		—		—
Funded status at December 31 — excess of obligation over assets	$	(172)	$	(192)	$	(75)	$	(84)

During the year ended December 31, 2023, the actuarial loss of $22 million on pension benefits was primarily driven by decreasing discount rates.

During the year ended December 31, 2022, the actuarial gain of $289 million on pension benefits was primarily driven by increasing discount rates.

Amounts recognized in NRG's balance sheets were as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Other current liabilities	$	—	$	—	$	5	$	7
Other non-current liabilities	172		192		70		77

Amounts recognized in NRG's accumulated OCI that have not yet been recognized as components of net periodic benefit cost were as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Net loss/(gain)	$	73	$	110	$	(14)	$	(7)
Prior service cost/(credit)	—		1		(4)		(12)
Total accumulated OCI	$	73	$	111	$	(18)	$	(19)

Other changes in plan assets and benefit obligations recognized in OCI were as follows:

	Year Ended December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Net actuarial (gain)/loss	$	(31)	$	74	$	(5)	$	(11)
Amortization of net actuarial loss	(6)		(3)		(1)		(2)
Amortization of prior service cost	—		—		8		8
Effect of settlement/curtailment	(1)		(14)		(1)		—
Total recognized in OCI	$	(38)	$	57	$	1	$	(5)
Net periodic benefit cost/(credit)	21		18		(3)		(4)
Net recognized in net periodic pension (credit)/cost and OCI	$	(17)	$	75	$	(2)	$	(9)

The following table presents the balances of significant components of NRG's pension plan:

	As of December 31,
	Pension Benefits
(In millions)	2023		2022
Projected benefit obligation	$	1,023	$	1,036
Accumulated benefit obligation	1,015		1,022
Fair value of plan assets	851		844

NRG's market-related value of its plan assets is the fair value of the assets. The fair values of the Company's pension plan assets by asset category and their level within the fair value hierarchy are as follows:

	Fair Value Measurements as of December 31, 2023
(In millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Total
Common/collective trust investment — U.S. equity	$	—	$	156	$	156
Common/collective trust investment — non-U.S. equity	—		58		58
Common/collective trust investment — non-core assets	—		81		81
Common/collective trust investment — fixed income	—		188		188
Short-term investment fund	19		—		19
Subtotal fair value	$	19	$	483	$	502
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					32
Common/collective trust investment — fixed income					243
Common/collective trust investment — non-core assets					47
Partnerships/joint ventures					27
Total fair value					$	851

	Fair Value Measurements as of December 31, 2022
(In millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Total
Common/collective trust investment — U.S. equity	$	—	$	155	$	155
Common/collective trust investment — non-U.S. equity	—		65		65
Common/collective trust investment — non-core assets	—		90		90
Common/collective trust investment — fixed income	—		181		181
Short-term investment fund	22		—		22
Subtotal fair value	$	22	$	491	$	513
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					33
Common/collective trust investment — fixed income					220
Common/collective trust investment — non-core assets					55
Partnerships/joint ventures					23
Total fair value					$	844

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 in its entirety. The fair value of the common/collective trust investments is valued at fair value which is equal to the sum of the market value of all of the fund's underlying investments. Certain common/collective trust investments have readily determinable fair value as they publish daily net asset value, or NAV, per share and are categorized as Level 2. Certain other common/collective trust investments and partnerships/joint ventures use NAV per share, or its equivalent, as a practical expedient for valuation, and thus have been removed from the fair value hierarchy table.

The following table presents the significant assumptions used to calculate NRG's benefit obligations:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
Weighted-Average Assumptions	2023		2022		2023		2022
Discount rate	4.97	%	5.18	%	4.96	%	5.19	%
Interest crediting rate	5.67	%	5.21	%	4.66	%	4.00	%
Rate of compensation increase	3.06	%	3.06	%	—		—
Health care trend rate	—		—		7.7% grading to 4.5% in 2033		7% grading to 4.4% in 2031

The following table presents the significant assumptions used to calculate NRG's benefit expense:

	As of December 31,
	Pension Benefits						Other Postretirement Benefits
Weighted-Average Assumptions	2023		2022		2021		2023		2022		2021
Discount rate	5.18	%	2.89%/4.71%/5.41%		2.55	%	5.19	%	2.82	%	2.81	%
Interest crediting rate	5.21	%	3.07	%	3.13	%	4.00	%	1.94	%	1.62	%
Expected return on plan assets	5.55	%	4.99	%	5.62	%	—		—		—
Rate of compensation increase	3.06	%	3.06	%	3.06	%	—		—		—
Health care trend rate	—		—		—		7.2% grading to 4.5% in 2028		6.9% grading to 4.4% in 2028		7.0% grading to 4.4% in 2028

NRG uses December 31 of each respective year as the measurement date for the Company's pension and other postretirement benefit plans. The Company sets the discount rate assumptions on an annual basis for each of NRG's defined benefit retirement plans as of December 31. The discount rate assumptions represent the current rate at which the associated liabilities could be effectively settled at December 31. The Company utilizes the Aon AA Above Median, or AA-AM, yield curve and the AON Canada yield curve to select the appropriate discount rate assumption for its retirement plans. The AA-AM yield curve is a hypothetical AA yield curve represented by a series of annualized individual spot discount rates from 6 months to 99 years. Under the AA-AM yield curve, each bond issue used to build this yield curve must be non-callable, and have an average rating of AA when averaging available Moody's Investor Services, Standard & Poor's and Fitch ratings. The AON Canada yield curve is based on high quality corporate bonds. Under the AON Canada yield curve, expected plan cash flows were discounted using the yield curve, and then a single rate is determined which produces an equivalent present value.

NRG employs a total return investment approach, whereby a mix of equities and fixed income investments are used to maximize the long-term return of plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan funded status, and corporate financial condition. The Investment Committee reviews the asset mix periodically and as the plan assets increase in future years, the Investment Committee may examine other asset classes such as real estate or private equity. NRG employs a building block approach to determining the long-term rate of return assumption for plan assets, with proper consideration given to diversification and rebalancing. Historical markets are studied and long-term historical relationships between equities and fixed income are preserved, consistent with the widely accepted capital market principle that assets with higher volatility generate a greater return over the long run. Current factors such as inflation and interest rates are evaluated before long-term capital market assumptions are determined. Peer data and historical returns are reviewed to check for reasonableness and appropriateness.

The target allocations of NRG's pension plan assets were as follows for the year ended December 31, 2023:

U.S. equity	19	%
Non-U.S. equity	12	%
Non-core assets	17	%
Fixed Income	52	%

Plan assets are currently invested in a diversified blend of equity and fixed-income investments. Furthermore, equity investments are diversified across U.S., non-U.S., global, and emerging market equities, as well as among growth, value, small and large capitalization stocks.

Investment risk and performance are monitored on an ongoing basis through quarterly portfolio reviews of each asset fund class to a related performance benchmark, if applicable, and annual pension liability measurements. Performance benchmarks are composed of the following indices:

Asset Class	Index
U.S. equities	Dow Jones U.S. Total Stock Market Index
Non-U.S. equities	MSCI All Country World Index
Non-core assets(a)	Various (per underlying asset class)
Fixed income securities	Barclays Short, Intermediate and Long Credits/Barclays Strips 20+ Index and FTSE Canada Universe Bond Index

(a)Non-Core Assets are defined as diversifying asset classes approved by the Investment Committee that are intended to enhance returns and/or reduce volatility of the U.S. and non-U.S. equities. Asset classes considered Non-Core include, but may not be limited to: Emerging Market Equity, Emerging Market Debt, Non-US Developed Market Small Cap, High Yield Fixed Income, Real Estate, Bank Loans, Global Infrastructure and other Alternatives

NRG's expected future benefit payments for each of the next five years, and in the aggregate for the five years thereafter, are as follows:

	Pension		Other Postretirement Benefit
(In millions)	Benefit Payments		Benefit Payments		Medicare Prescription Drug Reimbursements
2024	$	82	$	5	$	—
2025	81		5		—
2026	79		5		—
2027	78		5		—
2028	76		5		—
2029-2033	360		27		2

STP Defined Benefit Plans

STPNOC, which operates and maintains STP, provides its employees a defined benefit pension plan, as well as postretirement health and welfare benefits. Although NRG did not sponsor the STP plan, it reimbursed STPNOC for 44% of the contributions made towards its retirement plan obligations. For the years ended December 31, 2023 and December 31, 2022, NRG reimbursed STPNOC $3 million and $18 million, respectively, for its contribution to the plans. On November 1, 2023, the Company closed on the sale of its 44% equity interest in STP. Following the sale, the Company is no longer responsible for further reimbursements to the STP pension plan.     

The Company recognized the following in its statement of financial position, statement of operations and accumulated OCI related to its former 44% interest in STP:

	As of December 31,
	Pension Benefits		Other Postretirement Benefits
(In millions)	2022		2022
Funded status — STPNOC benefit plans	$	(7)	$	(13)
Net periodic benefit cost/(credit)	2		(4)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(27)		1

Defined Contribution Plans

NRG's employees are also eligible to participate in defined contribution 401(k) plans.

The Company's costs related to these plans were as follows:

	Year Ended December 31,
(In millions)	2023		2022		2021
Cost recognized for defined contribution plans	$	61	$	37	$	35

The Company's costs, which are primarily related to employer matching of a portion of employee contributions to defined contribution plans, increased during 2023 primarily due to an increase in retirement saving plan match and the Vivint acquisition.

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Capital Structure

12 Months Ended

Dec. 31, 2023

Equity [Abstract]

Capital Structure

Capital Structure

For the period from December 31, 2020 to December 31, 2023, the Company had 10,000,000 shares of preferred stock authorized and 500,000,000 shares of common stock authorized. The following table reflects the changes in NRG's preferred and common shares issued and outstanding for each period presented:

	Preferred Shares	Common Shares
	Issued and Outstanding	Issued	Treasury	Outstanding
Balance as of December 31, 2020	—	423,057,848	(178,825,915)	244,231,933
Shares issued under ESPP	—	—	117,392	117,392
Shares issued under LTIPs	—	489,326	—	489,326
Share repurchases	—	—	(1,084,752)	(1,084,752)
Balance as of December 31, 2021	—	423,547,174	(179,793,275)	243,753,899
Shares issued under ESPP	—	—	142,825	142,825
Shares issued under LTIPs	—	349,827	—	349,827
Share repurchases	—	—	(14,685,521)	(14,685,521)
Balance as of December 31, 2022	—	423,897,001	(194,335,971)	229,561,030
Issuance of Series A Preferred Stock	650,000	—	—	—
Shares issued under ESPP	—	—	191,249	191,249
Shares issued under LTIPs	—	1,109,611	—	1,109,611
Share repurchases	—	—	(22,730,940)	(22,730,940)
Retirement of treasury stock	—	(157,676,142)	157,676,142	—
Balance as of December 31, 2023	650,000	267,330,470	(59,199,520)	208,130,950
Shares issued under LTIPs	—	660,267	—	660,267
Share repurchases	—	—	(770,205)	(770,205)
Retirement of treasury stock	—	(770,205)	770,205	—
Balance as of February 1, 2024	650,000	267,220,532	(59,199,520)	208,021,012

Common Stock

As of December 31, 2023, NRG had 27,362,083 shares of common stock reserved for the maximum number of shares potentially issuable based on the conversion and redemption features of the long-term incentive plans.

Common Stock Dividends

The Company declared and paid $0.3775, $0.350 and $0.325 quarterly dividend per common share, or $1.51, $1.40 and $1.30 per share on an annualized basis for 2023, 2022 and 2021 respectively.

In 2021, 2022 and 2023, NRG increased the annual dividend on its common stock to $1.30, $1.40 and $1.51 per share, respectively, representing an 8% increase each year. The long-term capital allocation policy targets an annual dividend growth rate of 7%-9% per share in subsequent years. Beginning in the first quarter of 2024, NRG will increase the annual dividend by 8% to $1.63 per share.

The Company's common stock dividends are subject to available capital, market conditions, and compliance with associated laws, regulations and other contractual obligations.

On January 19, 2024, NRG declared a quarterly dividend on the Company's common stock of $0.4075 per share, or $1.63 per share on an annualized basis, payable on February 15, 2024, to stockholders of record as of February 1, 2024.

Employee Stock Purchase Plan 

The Company offers participation in the ESPP which allows eligible employees to elect to withhold between 1% and 10% of their eligible compensation to purchase shares of NRG common stock at the lesser of 90% of its market value on the offering date or 90% of the fair market value on the exercise date. An offering date occurs each April 1 and October 1. An exercise date occurs each September 30 and March 31. On April 27, 2023, NRG stockholders approved the adoption of the Amended and Restated Employee Stock Purchase Plan, effective April 1, 2023, which included a reduction in the price at which eligible employees may purchase shares of NRG common stock from 95% to 90% of the fair market value of the shares on the applicable date. NRG stockholders also approved an increase of 4,400,000 shares available for the issuance under the ESPP. As of December 31, 2023, there remained 6,702,125 shares of treasury stock reserved for issuance under the ESPP.

Share Repurchases

Share repurchases in 2021 and 2022 were made under the December 6, 2021 $1 billion authorization, as part of NRG’s capital allocation policy. On June 22, 2023, following the acquisition of Vivint Smart Home, NRG revised its long-term capital allocation policy to target allocating approximately 80% of cash available for allocation, after debt reduction, to be returned to shareholders. As part of the revised capital allocation framework, the Company announced an increase to its share repurchase authorization to $2.7 billion, to be executed through 2025.

On November 6, 2023, the Company executed Accelerated Share Repurchase agreements to repurchase a total of $950 million of NRG's outstanding common stock. Under the ASR agreements, the Company paid a total of $950 million and will receive shares of NRG's common stock on specified settlement dates. The total number of shares purchased pursuant to the ASR agreements will generally be based on the volume-weighted average prices of NRG's common stock during the term of each ASR agreement, less a discount. The Company received initial shares of 4,494,224 on November 8, 2023 and an additional 13,181,918 shares on December 27, 2023, which were recorded in treasury stock at fair value based on the volume-weighted average closing prices of $833 million, with the remaining $117 million recorded in additional paid in capital, representing the value of the forward contracts to purchase additional shares. On January 30, 2024, an additional 770,205 shares were delivered. The ASR period will end in March of 2024 and additional shares may be delivered upon final settlement of the remaining agreements. The total number of shares delivered and the average price paid for all of the shares delivered under the ASR agreements will be determined at the end of the ASR period.

During the year ended December 31, 2023, the Company completed $1.2 billion of share repurchases under the $2.7 billion authorization, including $950 million through the ASR and $200 million through open market repurchases at an average price of $39.56. As of February 1, 2024, $1.5 billion is remaining under the $2.7 billion authorization.

The following table summarizes the share repurchases made from 2021 through February 1, 2024:

	Total number of shares purchased	Average price paid per share		Amounts paid for shares purchased (in millions)
2021 Repurchases:
Open market repurchases(a)	1,084,752	$	40.85	$	44
2022 Repurchases:
Open market repurchases	14,685,521	40.48		595
2023 Repurchases:
Open market repurchases	5,054,798			200
Repurchases made under the accelerated share repurchase agreements(b)	17,676,142			950
Total Share Repurchases during 2023	22,730,940	(e)		$	1,150	(c)
Repurchases made subsequent to December 31, 2023 under the accelerated share repurchase agreements(d)	770,205			—
Total Share Repurchases January 1, 2023 through February 1, 2024	23,501,145	(e)		$	1,150

(a)Includes $5 million accrued as of December 31, 2021

(b)Initial and interim shares delivered under the November 6, 2023 accelerated share repurchase agreements

(c)Excludes $10 million accrued for excise tax owed as of December 31, 2023

(d)Additional shares delivered under the November 6, 2023 accelerated share repurchase agreements

(e)The total number of shares delivered and the average price per share under the ASR agreements will be determined at the end of the ASR period

Retirement of Treasury Stock

In the fourth quarter of 2023, the Company retired 157,676,142 shares of treasury stock. These retired shares are now included in NRG's pool of authorized but unissued shares. The retired stock had a carrying value of approximately $5.0 billion. The Company's accounting policy upon the formal retirement of treasury stock is to deduct its par value from common stock and to reflect any excess of cost over par value as a deduction from additional paid-in capital.

Preferred Stock

Series A Preferred Stock

On March 9, 2023 ("Series A Issuance Date"), the Company issued 650,000 shares of 10.25% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock. The net proceeds of $635 million, net of issuance costs, were used to partially fund the Vivint Smart Home acquisition.

The Series A Preferred Stock is not convertible into or exchangeable for any other securities or property and has limited voting rights. The Series A Preferred Stock may be redeemed, in whole or in part, on one or more occasions, at the option of the

Company at any time after March 15, 2028 ("Series A First Reset Date") and in certain other circumstances prior to the Series A First Reset Date. The Series A Preferred Stock has a liquidation preference of $1,000 per share, plus accumulated but unpaid dividends.

Series A Preferred Stock Dividends

The annual dividend rate on each share of Series A Preferred Stock is 10.25% from the Series A Issuance Date to, but excluding the Series A First Reset Date. On and after the Series A First Reset Date, the dividend rate on each share of Series A Preferred Stock shall equal the five-year U.S. Treasury rate as of the most recent reset dividend determination date (subject to a floor of 1.00%), plus a spread of 5.92% per annum. Cumulative cash dividends on the Series A Preferred Stock are payable semiannually, in arrears, on each March 15 and September 15, when, as and if declared by the Board of Directors. In September 2023, the Company declared and paid a semi-annual dividend of $52.96 per share on its outstanding Series A Preferred Stock, totaling $34 million.

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Investments Accounted for by the Equity Method and Variable Interest Entities

12 Months Ended

Dec. 31, 2023

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 not Consolidated

NRG accounts for the Company's significant investments using the equity method of accounting. NRG's carrying value of equity investments can be impacted by a number of elements including impairments and movements in foreign currency exchange rates.

The following table summarizes NRG's equity method investments as of December 31, 2023:

(In millions, except percentages)
Name:	Economic Interest		Investment Balance
Gladstone	37.5	%	$	34
Midway-Sunset Cogeneration Company	50.0	%	8
Total equity investments in affiliates			$	42

The following table summarizes the undistributed earnings from NRG's equity method investments as of December 31, 2023:

	As of December 31,
(In millions)	2023		2022
Undistributed earnings	$	—	$	42

Other Equity Investments

Gladstone — Through a joint venture, NRG owns a 37.5% interest in Gladstone, a 1,613 MW coal-fueled power generation facility in Queensland, Australia. The power generation facility is managed by the joint venture participants and the facility is operated by NRG. Operating expenses incurred in connection with the operation of the facility are funded by each of the participants in proportion to their ownership interests. Coal is sourced from local mines in Queensland. NRG and the joint venture participants receive their respective share of revenues directly from the off takers in proportion to the ownership interests in the joint venture. Power generated by the facility is primarily sold to an adjacent aluminum smelter, with excess power sold to the Queensland Government-owned utility under long-term supply contracts. NRG's investment in Gladstone was $34 million as of December 31, 2023.

Entities that are Consolidated

The Company has a controlling financial interest that has been identified as a VIE under ASC 810 in NRG Receivables LLC, which has entered into financing transactions related to the Receivables Facility as further described in Note 13, Long-term Debt and Finance Leases.

The summarized financial information for the Company's consolidated VIEs consisted of the following:

(In millions)	December 31, 2023		December 31, 2022
Accounts receivable and Other current assets	$	1,541	$	2,108
Current liabilities	153		152
Net assets	$	1,388	$	1,956

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(Loss)/Income Per Share

12 Months Ended

Dec. 31, 2023

Earnings Per Share [Abstract]

(Loss)/Income Per Share

(Loss)/Income Per Share

Basic (loss)/income per common share is computed by dividing net (loss)/income less cumulative dividends attributable to preferred stock by the weighted average number of common shares outstanding. Shares issued and treasury shares repurchased during the year are weighted for the portion of the year that they were outstanding. Diluted (loss)/income per share is computed in a manner consistent with that of basic (loss)/income per share, while giving effect to all potentially dilutive common shares that were outstanding during the period.

Dilutive effect for equity compensation and other equity instruments — The relative performance stock units, non-vested restricted stock units, market stock units and non-qualified stock options are not considered outstanding for purposes of computing basic (loss)/income per share. However, these instruments are included in the denominator for purposes of computing diluted (loss)/income per share under the treasury stock method for periods when there is net income. The Convertible Senior Notes are convertible, under certain circumstances, into cash or combination of cash and Company’s common stock. Prior to adoption of ASU 2020-06, there was no dilutive effect for the Convertible Senior Notes due to the Company’s expectation to settle the liability in cash. Upon adoption of ASU 2020-06, on January 1, 2022, the Company is including the potential share settlements, if any, in the denominator for purposes of computing diluted (loss)/income per share under the if converted method for periods when there is net income. The potential shares settlements are calculated as the excess of the Company's conversion obligation over the aggregate principal amount (which will be settled in cash), divided by the average share price for the period. For the year ended December 31, 2023, there was no dilutive effect for the Convertible Senior Note since there was a net loss. For the year ended December 31, 2022, there was no dilutive effect for the Convertible Senior Notes since there were no potential share settlements for the period.

The reconciliation of NRG's basic and diluted (loss)/income per share is shown in the following table:

	Year Ended December 31,
(In millions, except per share amounts)	2023		2022		2021
Basic and diluted (loss)/income per share:
Net (loss)/income	$	(202)	$	1,221	$	2,187
Less: Cumulative dividends attributable to Series A Preferred Stock	54		—		—
(Loss)/Income Available to Common Stockholders	$	(256)	$	1,221	$	2,187
Weighted average number of common shares outstanding - basic and diluted	228		236		245
(Loss)/Income per weighted average common share — basic and diluted	$	(1.12)	$	5.17	$	8.93

As of December 31, 2023, the Company had 6 million of outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company's diluted loss per share. As of December 31, 2022 and 2021, the Company had an insignificant number of outstanding equity instruments that are anti-dilutive and were not included in the computation of the Company’s diluted income per share.

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Segment Reporting

12 Months Ended

Dec. 31, 2023

Segment Reporting [Abstract]

Segment Reporting

Segment Reporting

The Company’s segment structure reflects how management makes financial decisions and allocates resources. The Company manages its operations based on the combined results of the retail and wholesale generation businesses with a geographical focus. Vivint Smart Home operations are reported within the Vivint Smart Home segment.

NRG's chief operating decision maker, its interim 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, free cash flow and allocation of capital, as well as net income/(loss). The accounting policies of the segments are the same as those applied in the consolidated financial statements as disclosed in Note 2, Summary of Significant Accounting Policies.

The Company had no customer that comprised more than 10% of the Company's consolidated revenues during the years ended December 31, 2023, 2022 and 2021.

Intersegment sales are accounted for at market.

	For the Year Ended December 31, 2023
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate(b)		Eliminations		Total
Revenue(b)	$	10,476	$	12,547	$	4,281	$	1,549	$	—	$	(30)	$	28,823
Operating expenses	8,407		14,412		5,025		917		133		(30)		28,864
Depreciation and amortization	294		116		95		586		36		—		1,127
Impairment losses	2		4		20		—		—		—		26
Total operating cost and expenses	8,703		14,532		5,140		1,503		169		(30)		30,017
Gain on sale of assets	1,319		259		—		—		—		—		1,578
Operating income/(loss)	3,092		(1,726)		(859)		46		(169)		—		384
Equity in earnings of unconsolidated affiliates	—		—		16		—		—		—		16
Impairment losses on investments	—		—		(102)		—		—		—		(102)
Other income, net	2		11		6		(12)		56		(16)		47
Gain on debt extinguishment	—		—		—		—		109		—		109
Interest expense	(3)		(3)		(31)		(177)		(469)		16		(667)
Income/(loss) before income taxes	3,091		(1,718)		(970)		(143)		(473)		—		(213)
Income tax (benefit)/expense(c)	—		—		(111)		(32)		132		—		(11)
Net income/(loss)	$	3,091	$	(1,718)	$	(859)	$	(111)	$	(605)	$	—	$	(202)
Balance sheet
Equity investments in affiliates	$	—	$	—	$	42	$	—	$	—	$	—	$	42
Capital expenditures	495		5		27		18		53		—		598
Goodwill	643		721		221		3,494		—		—		5,079
Total assets	$	8,236	$	13,712	$	3,626	$	7,043	$	19,919	$	(26,498)	$	26,038

(a) Includes results of operations following the acquisition date of March 10, 2023
(b) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	5	$	9	$	16	$	—	$	—	$	—	$	30
(c) Consolidated domestic federal and state income taxes are recorded to the Corporate segment, except for Vivint Smart Home which is recorded directly to the Vivint Smart Home segment. West/Services/Other amounts represent foreign income taxes

	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenue(a)	$	10,057	$	16,763	$	4,706	$	—	$	17	$	31,543
Operating expenses	8,495		16,031		4,108		86		17		28,737
Depreciation and amortization	310		208		85		31		—		634
Impairment losses	—		206		—		—		—		206
Total operating cost and expenses	8,805		16,445		4,193		117		17		29,577
Gain/(loss) on sale of assets	10		—		45		(3)		—		52
Operating income/(loss)	1,262		318		558		(120)		—		2,018
Equity in (losses)/earnings of unconsolidated affiliates	(2)		—		8		—		—		6
Other income, net	5		10		3		54		(16)		56
Interest expense	—		(1)		(32)		(400)		16		(417)
Income/(loss) before income taxes	1,265		327		537		(466)		—		1,663
Income tax expense(b)	—		1		57		384		—		442
Net income/(loss)	$	1,265	$	326	$	480	$	(850)	$	—	$	1,221
Balance sheet
Equity investments in affiliates	$	—	$	—	$	133	$	—	$	—	$	133
Capital expenditures	273		7		37		50		—		367
Goodwill	710		723		217		—		—		1,650
Total assets	$	11,475	$	19,526	$	8,139	$	35,780	$	(45,774)	$	29,146

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	4	$	(26)	$	5	$	—	$	—	$	(17)
(b) Consolidated domestic federal and state income taxes are recorded to the Corporate segment. West/Services/Other amounts represent foreign income taxes

	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenue(a)	$	10,295	$	13,025	$	3,659	$	—	$	10	$	26,989
Operating expenses	8,692		10,256		3,467		141		10		22,566
Depreciation and amortization	336		333		88		28		—		785
Impairment losses	—		535		9		—		—		544
Total operating cost and expenses	9,028		11,124		3,564		169		10		23,895
Gain on sale of assets	19		—		17		211		—		247
Operating income	1,286		1,901		112		42		—		3,341
Equity in (losses)/earnings of unconsolidated affiliates	(3)		—		20		—		—		17
Other income, net	8		7		3		59		(14)		63
Loss on debt extinguishment	—		—		—		(77)		—		(77)
Interest expense	(1)		(1)		(28)		(469)		14		(485)
Income/(loss) before income taxes	1,290		1,907		107		(445)		—		2,859
Income tax expense(b)	—		—		19		653		—		672
Net income/(loss)	$	1,290	$	1,907	$	88	$	(1,098)	$	—	$	2,187

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	5	$	(18)	$	3	$	—	$	—	$	(10)
(b) Consolidated domestic federal and state income taxes are recorded to the Corporate segment. West/Services/Other amounts represent foreign income taxes

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Income Taxes

12 Months Ended

Dec. 31, 2023

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

The income tax provision consisted of the following amounts:

	Year Ended December 31,
(In millions, except effective income tax rate)	2023			2022			2021
Current
U.S. Federal	$	26		$	3		$	—
State	84			65			48
Foreign	(12)			3			3
Total — current	98			71			51
Deferred
U.S. Federal	50			258			569
State	(61)			59			36
Foreign	(98)			54			16
Total — deferred	(109)			371			621
Total income tax (benefit)/expense	$	(11)		$	442		$	672
Effective income tax rate	5.2		%	26.6		%	23.5		%

The IRA enacted on August 16, 2022, introduced new provisions including a 15% corporate alternative minimum tax and a 1% excise tax on net share repurchases with both taxes effective beginning in fiscal year 2023 for NRG. There is no impact on the Company's provision for income taxes from the CAMT for the year ended December 31, 2023. The Company will reevaluate the impact of the corporate alternative minimum tax upon the potential release of guidance by the U.S. Treasury and the IRS regarding the treatment of unrealized gains and losses on derivative instruments.

The following represented the domestic and foreign components of income before income taxes:

	Year Ended December 31,
(In millions)	2023		2022		2021
U.S.	$	261	$	1,436	$	2,759
Foreign	(474)		227		100
Total	$	(213)	$	1,663	$	2,859

Reconciliations of the U.S. federal statutory tax rate to NRG's effective tax rate were as follows:

	Year Ended December 31,
(In millions, except effective income tax rate)	2023			2022			2021
(Loss)/Income before income taxes	$	(213)		$	1,663		$	2,859
Tax at federal statutory tax rate	(45)			349			600
State taxes	(22)			69			111
Foreign rate differential	(10)			7			(3)
Changes in state valuation allowances	42			(3)			(29)
Permanent differences	31			17			8
Recognition of uncertain tax benefits	12			8			(10)
Deferred impact of state tax rate changes	3			14			(10)
Foreign tax refunds	(17)			—			—
Return to provision adjustments	(5)			—			5
Carbon capture tax credits	—			(19)			—
Income tax (benefit)/expense	$	(11)		$	442		$	672
Effective income tax rate	5.2		%	26.6		%	23.5		%

For the year ended December 31, 2023, NRG's effective income tax rate was lower than the federal statutory tax rate of 21%, primarily due to permanent differences and changes in state valuation allowances.

For the year ended December 31, 2022, NRG's effective income tax rate was higher than the federal statutory tax rate of 21% primarily due to state tax expense partially offset by the recognition of carbon capture tax credits.

For the year ended December 31, 2021, NRG's effective income tax rate was higher than the federal statutory tax rate of 21% primarily due to state tax expense partially offset by tax benefits from the revaluation of state deferred tax assets, valuation allowance, and settlements of uncertain tax positions.

The temporary differences, which gave rise to the Company's deferred tax assets and liabilities consisted of the following:

	As of December 31,
(In millions)	2023		2022
Deferred tax assets:
U.S. Federal net operating loss carryforwards	$	1,762	$	1,717
State net operating loss carryforwards	367		315
Foreign net operating loss carryforwards	110		104
Deferred revenues	347		—
Difference between book and tax basis of property	353		399
Federal and state tax credit carryforwards	317		393
Deferred compensation, accrued vacation and other reserves	141		93
Interest disallowance carryforward per §163(j) of the Tax Act	132		65
Pension and other postretirement benefits	48		62
Allowance for credit losses	35		33
Equity compensation	24		8
Federal benefit on state uncertain tax positions	13		5
Inventory obsolescence	11		10
U.S. capital loss	1		15
Other	33		22
Total deferred tax assets	3,694		3,241
Deferred tax liabilities:
Intangibles amortization (excluding goodwill)	726		269
Derivatives	156		874
Capitalized contract costs	131		—
Equity method investments	93		82
Goodwill	40		26
Debt discount amortization	26		—
Emissions allowances	18		19
Total deferred tax liabilities	1,190		1,270
Total deferred tax assets less deferred tax liabilities	2,504		1,971
Valuation allowance	(275)		(224)
Total net deferred tax assets, net of valuation allowance	$	2,229	$	1,747

The following table summarizes NRG's net deferred tax position as presented in the consolidated balance sheets:

	As of December 31,
(In millions)	2023		2022
Deferred tax asset	$	2,251	$	1,881
Deferred tax liability	(22)		(134)
Net deferred tax asset	$	2,229	$	1,747

The primary drivers for the increase in the net deferred tax asset from $1.7 billion as of December 31, 2022 to $2.2 billion as of December 31, 2023 is due to unrealized mark-to-market book losses and deferred revenues, partially offset by capitalized contract costs and a step-up in basis of book intangibles associated with the acquisition of Vivint Smart Home.

Deferred tax assets and valuation allowance

Net deferred tax balance — As of December 31, 2023 and 2022, NRG recorded a net deferred tax asset, excluding valuation allowance, of $2.5 billion and $2.0 billion, respectively. The Company believes certain state net operating losses may not be realizable under the more-likely-than-not measurement and as such, a valuation allowance was recorded as of December 31, 2023 as discussed below.

NOL carryforwards — As of December 31, 2023, the Company had tax-effected cumulative U.S. NOLs consisting of carryforwards for federal and state income tax purposes of $1.8 billion and $367 million, respectively. In addition, NRG has tax-effected cumulative foreign NOL carryforwards of $110 million. The majority of NRG's NOL carryforwards have no expiration date.

 Valuation allowance — As of December 31, 2023, the Company's tax-effected valuation allowance was $275 million, consisting of state NOL carryforwards and foreign NOL carryforwards. The valuation allowance was recorded based on the assessment of cumulative and forecasted pre-tax book earnings and the future reversal of existing taxable temporary differences.

Taxes Receivable and Payable

As of December 31, 2023, NRG recorded a current federal payable of $20 million, a current net state payable of $3 million and a current net foreign receivable of $7 million.

Uncertain tax benefits

NRG has identified uncertain tax benefits with after-tax value of $73 million and $22 million as of December 31, 2023 and 2022, for which NRG has recorded a non-current tax liability of $76 million and $24 million, respectively. The Company recognizes interest and penalties related to uncertain tax benefits in income tax expense. The Company recognized $1 million of interest expense for the year ended December 31, 2023, $1 million for the year ended 2022 and an immaterial amount for the year ended 2021. As of December 31, 2023 and 2022, NRG had cumulative interest and penalties related to these uncertain tax benefits of $3 million and $2 million, respectively.

Tax jurisdictions — NRG is subject to examination by taxing authorities for income tax returns filed in the U.S. federal jurisdiction and various state and foreign jurisdictions including operations located in Australia and Canada.

The Company is no longer subject to U.S. federal income tax examinations for years prior to 2020. With few exceptions, state and Canadian income tax examinations are no longer open for years before 2015.

The following table summarizes uncertain tax benefits activity:

	As of December 31,
(In millions)	2023		2022
Balance as of January 1	$	22	$	13
Increase due to current year positions	28		9
Increase due to acquired balance from Vivint Smart Home	23		—
Uncertain tax benefits as of December 31	$	73	$	22

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Stock-Based Compensation

12 Months Ended

Dec. 31, 2023

Share-Based Payment Arrangement, Noncash Expense [Abstract]

Stock-Based Compensation

Stock-Based Compensation

The Company's stock-based compensation consists of awards granted under the NRG LTIP and following the Acquisition in March 2023, the Vivint LTIP.

NRG Energy, Inc. Long-Term Incentive Plan

As of December 31, 2023 and 2022, a total of 25,000,000 shares of NRG common stock were authorized for issuance under the NRG LTIP. There were 7,717,139 and 8,179,771 shares of common stock remaining available for grants under the NRG LTIP as of December 31, 2023 and 2022, respectively. The NRG LTIP is subject to adjustments in the event of reorganization, recapitalization, stock split, reverse stock split, stock dividend, and a combination of shares, merger or similar change in NRG's structure or outstanding shares of common stock. As of December 31, 2023, the outstanding awards under the NRG LTIP include restricted stock units, deferred stock units and relative performance stock units.

Restricted Stock Units

As of December 31, 2023, RSUs granted under the NRG LTIP typically have three-year graded vesting schedules beginning on the grant date. Fair value of the RSUs granted during 2023 and 2022 is derived from the closing price of NRG common stock on the grant date. The following table summarizes the Company's non-vested RSU awards and changes during the year:

	Units	Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2022	856,917	$	40.25
Granted	1,031,469	35.71
Forfeited	(284,076)	34.70
Vested	(393,470)	39.67
Non-vested at December 31, 2023	1,210,840	37.88

The total fair value of RSUs vested during the years ended December 31, 2023, 2022 and 2021 was $20 million, $10 million and $12 million, respectively. The weighted average grant date fair value of RSUs granted during the years ended December 31, 2023, 2022 and 2021 was $35.71, $41.26 and $39.00, respectively.

Deferred Stock Units

DSUs represent the right of a participant to be paid one share of NRG common stock at the end of a deferral period established under the terms of the award. DSUs granted under the NRG LTIP are fully vested at the date of issuance. Fair value of the DSUs, which is based on the closing price of NRG common stock on the date of grant, is recorded as compensation expense in the period of grant.

The following table summarizes the Company's outstanding DSU awards and changes during the year:

	Units	Weighted Average Grant Date Fair Value per Unit
Outstanding at December 31, 2022	418,014	$	27.63
Granted	79,072	34.40
Converted to Common Stock	(53,799)	25.11
Outstanding at December 31, 2023	443,287	29.07

The aggregate intrinsic values for DSUs outstanding as of December 31, 2023, 2022 and 2021 were approximately $23 million, $13 million and $17 million, respectively. The aggregate intrinsic values for DSUs converted to common stock for the years ended December 31, 2023, 2022 and 2021 were $3 million, $1 million and $1 million, respectively. The weighted average grant date fair value of DSUs granted during the years ended December 31, 2023, 2022 and 2021 was $34.40, $45.49 and $32.27, respectively.

Relative Performance Stock Units

RPSUs entitle the recipient to stock upon vesting. The amount of the award is subject to the Company's achievement of certain performance measures over the vesting period. RPSUs are restricted grants where the quantity of shares increases and decreases alongside the Company's Total Shareholder Return ("TSR"), relative to the TSR of the Company's current proxy peer group and the total returns of select indexes, or Peer Group. For RPSU's granted in 2022 and forward, the peer group consists of the companies that comprise the Standard & Poor’s 500 Index on the first day of the performance period. Each RPSU represents the potential to receive NRG common stock after the completion of the performance period, typically three years of service from the date of grant. The number of shares of NRG common stock to be paid (if any) as of the vesting date for each RPSU will depend on the Company’s percentile rank within the Peer Group. The number of shares of common stock to be paid as of the vesting date for each RPSU is linearly interpolated for TSR performance between the following points: (i) 0% if ranked below the 25th percentile; (ii) 25% if ranked at the 25th percentile; (iii) 100% if ranked at the 55th percentile (or the 65th percentile if the Company's absolute TSR is less than negative 15%); and (iv) 200% if ranked at the 75th percentile or above.

The following table summarizes the Company's non-vested RPSU awards and changes during the year:

	Units	Weighted Average Grant-Date Fair Value per Unit
Non-vested at December 31, 2022	795,335	$	50.23
Granted	617,510	39.46
Forfeited(a)	(737,227)	45.61
Vested	(3,729)	50.28
Non-vested at December 31, 2023	671,889	46.27

(a)Includes January 2023 vestings that occurred at a 0% payout as well as forfeitures due to the departure of certain officers

The weighted average grant date fair value of RPSUs granted during the years ended December 31, 2023, 2022 and 2021, was $39.46, $57.41 and $46.78, respectively.

The fair value of RPSUs is estimated on the date of grant using a Monte Carlo simulation model and expensed over the service period, which equals the vesting period. Significant assumptions used in the fair value model with respect to the Company's RPSUs are summarized below:

	2023		2022		2021(a)
Expected volatility	41.35	%	37.54	%	34.05	%
Expected term (in years)	3		3		3
Risk free rate	4.18	%	0.97	%	0.17	%

(a)Assumptions pertain to the main award granted in January 2021. Additional 60,815 RPSUs were granted in September 2021 with a risk free rate of 0.42% and expected volatility of 37.38%

The expected volatility is calculated based on NRG's historical stock price volatility data over the period commensurate with the expected term of the RPSU, which equals the vesting period.

Vivint Smart Home Long-Term Incentive Plan

Effective March 10, 2023, in connection with the Vivint Smart Home Acquisition, as discussed in Note 4, Acquisitions and Dispositions, NRG assumed the Vivint Smart Home, Inc. Long-Term Incentive Plan, or Vivint LTIP. In addition to the rollover awards converted as part of the Acquisition, the Vivint LTIP provides for issuances of time-based restricted stock units and performance-based restricted stock units. As of December 31, 2023, 17,500,000 shares of NRG common stock were authorized for issuance under the Vivint LTIP, and there were 12,749,736 shares of common stock remaining available for grants.

Restricted Stock Units

As of December 31, 2023, RSUs under the Vivint LTIP include RSUs which were granted prior to the Acquisition and were converted into awards that will vest as NRG common stock ("Rollover RSUs"). These awards typically had four-year graded vesting schedules beginning on the grant date. The fair value of the Rollover RSUs is based on the fair value of NRG common stock on the Acquisition date after applying the conversion ratio as per the Merger Agreement. The RSUs that were granted following the Acquisition date are typically subject to the same terms as the RSUs under the NRG LTIP.

The following table summarizes the non-vested RSUs under the Vivint LTIP and changes during the year:

	Rollover RSUs			RSUs granted following the Acquisition
	Units	Weighted Average Grant Date Fair Value per Unit		Units	Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2022	—	$	—	—	$	—
Rollover RSUs at the Acquisition date	4,553,998	31.63		—	—
Granted following the Acquisition date	—	—		895,827	35.24
Forfeited	(288,776)	31.63		(110,531)	35.21
Vested	(1,280,321)	31.63		(4,998)	35.21
Non-vested at December 31, 2023	2,984,901	31.63		780,298	35.24

The total fair value of RSUs vested during the year ended December 31, 2023 was $66 million.

Performance Stock Units

As of December 31, 2023, PSUs granted under the Vivint LTIP are generally granted under the same terms as the PSUs granted under the NRG LTIP, and are valued using the same methods and assumptions. During the year ended December 31, 2023, 102,837 PSUs were granted at a weighted average grant date fair value per unit of $44.96 and remain outstanding as of year end.

Supplemental Information

The following table summarizes NRG's total compensation expense recognized for the years presented, as well as total non-vested compensation costs not yet recognized and the period over which this expense is expected to be recognized as of December 31, 2023, for each of the types of awards issued under the LTIPs. Minimum tax withholdings of $22 million, $6 million, and $9 million for the years ended December 31, 2023, 2022, and 2021, respectively, are reflected as a reduction to additional paid-in capital on the Company's consolidated balance sheets.

							Non-vested Compensation Cost
(In millions, except weighted average data)	Compensation Expense						Unrecognized Total Cost		Weighted Average Recognition Period Remaining (In years)
	Year Ended December 31,						As of December 31,
Award	2023		2022		2021		2023		2023
RSUs under NRG LTIP	$	20	$	15	$	9	$	29	1.61
RSUs under Vivint LTIP	76		—		—		69		1.82
PSUs under Vivint LTIP	2		—		—		3		2.25
DSUs	2		2		2		—		0.00
RPSUs	3		11		9		17		1.69
PRSUs under NRG LTIP(a)	12		6		7		15		1.74
PRSUs under Vivint LTIP(a)	8		—		—		14		2.29
Total	$	123	$	34	$	27	$	147
Tax detriment recognized	$	2	$	3	$	2

(a)Phantom Restricted Stock Units, PRSUs, are liability-classified time-based awards that typically vest ratably over a three-year period. The amount to be paid upon vesting is based on NRG's closing stock price for the period

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Related Party Transactions

12 Months Ended

Dec. 31, 2023

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

NRG provides services to some of its related parties, who are accounted for as equity method investments, under operations and maintenance agreements. Fees for the services under these agreements include recovery of NRG's costs of operating the plants. Certain agreements also include fees for administrative service, a base monthly fee, profit margin and/or annual incentive bonus.

The following table summarizes NRG's material related party transactions with third-party affiliates:

	Year Ended December 31,
(In millions)	2023		2022		2021
Revenues from Related Parties Included in Revenues
Gladstone	$	4	$	4	$	4
Ivanpah(a)	78		42		39
Midway-Sunset	2		6		6
Total	$	84	$	52	$	49

(a)Includes fees under project management agreements with each project company

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Commitments and Contingencies

12 Months Ended

Dec. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Commitments

NRG has entered into long-term contractual arrangements related to energy products, including power purchases, gas transportation and storage, and fuel and transportation services. These contracts are not included in the consolidated balance sheet as of December 31, 2023.

As of December 31, 2023, the Company's minimum commitments under such outstanding agreements are estimated as follows:

Period	(In millions)
2024	$	573
2025	836
2026	540
2027	364
2028	292
Thereafter	823
Total(a)	$	3,428

(a)The year 2024 does not include an additional $978 million of short-term commitments

The Company's actual costs may be significantly higher than these estimated minimum unconditional long-term firm commitments with remaining term in excess of one year. For the years ended December 31, 2023, 2022 and 2021, the costs of fuel and purchased energy were $13.4 billion, $19.6 billion and $13.4 billion, respectively.

First Lien Structure

NRG has granted first liens to certain counterparties on a substantial portion of property and assets owned by NRG and the guarantors of its senior debt. NRG uses the first lien structure to reduce the amount of cash collateral and letters of credit that it would otherwise be required to post from time to time to support its obligations under out-of-the-money hedges. To the extent that the underlying hedge positions for a counterparty are out-of-the-money to NRG, the counterparty would have a claim under the first lien program. As of December 31, 2023, all hedges under the first liens were in-the-money on a counterparty aggregate basis.

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. NRG records accruals 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 accrual for the applicable legal matters, including regulatory and environmental matters as further discussed in Note 24, Regulatory Matters, and Note 25, Environmental Matters. In addition, legal costs are expensed as incurred. Management has assessed each of the following matters based on current information and made a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought, and the probability of success. Unless specified below, the Company is unable to predict the outcome of these legal proceedings 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 accruals and that such difference could be material.

In addition to the legal proceedings noted below, NRG 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 NRG's consolidated financial position, results of operations, or cash flows.

Environmental Lawsuits

Sierra club et al. v. Midwest Generation LLC — In 2012, several environmental groups filed a complaint against Midwest Generation with the Illinois Pollution Control Board ("IPCB") alleging violations of environmental law resulting in groundwater contamination. In June 2019, the IPCB found in an interim order that Midwest Generation violated the law because it had improperly handled coal ash at four facilities in Illinois and caused or allowed coal ash constituents to impact groundwater. On September 9, 2019, Midwest Generation filed a Motion to Reconsider numerous issues, which the court granted in part and denied in part on February 6, 2020. In 2023, the IPCB held hearings to determine the appropriate relief. Midwest Generation has been working with the Illinois EPA to address the groundwater issues since 2010.

Consumer Lawsuits

Similar to other energy service companies operating in the industry, from time-to-time, the Company and/or its subsidiaries may be subject to consumer lawsuits in various jurisdictions where they sell natural gas and electricity.

Variable Price Cases — In the cases set forth below, referred to as the Variable Price Cases, such actions involve consumers alleging that one of the Company’s ESCOs promised that consumers would pay the same or less than they would have paid if they stayed with their default utility or previous energy supplier. The underlying claims of each case are similar and the Company continues to deny the allegations and is vigorously defending these matters. These matters were known and accrued for at the time of each acquisition.

XOOM Energy

Mirkin v. XOOM Energy (E.D.N.Y. Aug. 2019) is a defendant in a putative class action lawsuit pending in New York. The Court denied XOOM's motion for summary judgment and granted class certification. The Second Circuit denied XOOM's request to appeal the class certification grants. XOOM plans to challenge Mirkin's expert testimony to further hamper Mirkin's ability to support its case.

Direct Energy

There was one putative class action pending against Direct Energy: Richard Schafer v. Direct Energy (W.D.N.Y. Dec. 2019; on appeal 2nd Cir. N.Y.) - The Second Circuit sent the matter back to the trial court in December 2021. After discovery, Direct Energy filed summary judgment. Direct Energy won summary judgment and Schafer appealed. The appeal is fully briefed. Oral argument occurred on October 25, 2023. The Second Circuit upheld the trial court's grant of summary judgment in favor of Direct Energy.

Telephone Consumer Protection Act ("TCPA") Cases — In the cases set forth below, referred to as the TCPA Cases, such actions involve consumers alleging violations of the Telephone Consumer Protection Act of 1991, as amended, by receiving calls, texts or voicemails without consent in violation of the federal Telemarketing Sales Rule, and/or state counterpart legislation. The underlying claims of each case are similar. The Company denies the allegations asserted by plaintiffs and intends to vigorously defend these matters. These matters were known and accrued for at the time of the acquisition.

There are two putative class actions pending against Direct Energy: (1) Holly Newman v. Direct Energy, LP (D. Md Sept 2021) - Direct Energy filed its Motion to Dismiss asserting the ruling in the Brittany Burk v. Direct Energy (S.D. Tex. Feb 2019) preempts the Plaintiff's ability to file suit based on the same facts. The Court denied Direct Energy's motion stating the Court does not have the benefit of all of the facts that were in front of the Burk court to issue a similar ruling. On October 19, 2022, Direct Energy filed a Motion to Transfer Venue asking the Court to transfer the case to the Southern District where the Burk case was filed. On April 12, 2023, the Court granted Direct Energy’s Motion to Transfer Venue, moving to the case to the Southern District of Texas; and (2) Matthew Dickson v. Direct Energy (N.D. Ohio Jan. 2018) - The case was stayed pending the outcome of an appeal to the Sixth Circuit based on the unconstitutionality of the TCPA during the period from 2015-2020. The Sixth Circuit found the TCPA was in effect during that period and remanded the case back to the trial court. Direct Energy refiled its motions along with supplements. On March 25, 2022, the Court granted summary judgment in favor of Direct Energy and dismissed the case. Dickson appealed. The Sixth Circuit found that Dickson has standing and reversed the trial court's dismissal of the case. The matter is back at the trial court. The parties will conduct further fact discovery and expert discovery and are likely to resubmit motions for further review by the Court.

Sales Practice Lawsuits

There are three litigation matters relating to claims made by Vivint Smart Home competitors against Vivint Smart Home alleging, among other things, that Vivint Smart Home's sales representatives used deceptive sales practices. These matters were known and accrued for at the time of the acquisition. The three matters are: (1) CPI Security Systems, Inc. ("CPI") v. Vivint Smart Home, Inc. (W.D.N.C. Sept. 2020). The CPI matter that was filed in 2020 went to trial, and in February 2023, the jury issued a verdict against Vivint Smart Home, in favor of CPI for $50 million of compensatory damages and an additional $140 million of punitive damages. Vivint Smart Home has filed its notice of appeal and is awaiting a briefing schedule. While Vivint Smart Home believes the CPI jury verdict is not legally or factually supported and intends to pursue post judgment remedies and file an appeal, there can be no assurance that such defense efforts will be successful; (2) ADT LLC, et al. ("ADT") v. Vivint Smart Home, Inc. f/k/a Mosaic Acquisition Corporation, et al.(S.D.Fl. Aug. 2020). The parties mediated in May 2023 and agreed on a settlement. In June 2023, the Court granted final approval of the settlement, which was paid in June 2023; and (3) Alert 360 Opco, Inc, et al. ("Alert 360") v. Vivint Smart Home, Inc., et al (N.D.Ok. March 2023). On March 1, 2023, Alert 360 filed a complaint against Vivint Smart Home alleging, among other things, deceptive sales practices. The parties settled the dispute in October 2023 and the case was dismissed.

Patent Infringement Lawsuits

SB IP Holdings LLC (“Skybell”) v. Vivint Smart Home, Inc. — On October 23, 2023, a jury in the U.S. District Court, Eastern District of Texas, Sherman Division, issued a verdict against the Company in favor of Skybell for $45 million in damages for patent infringement. The patents that were the basis for the claims made by Skybell were ruled invalid by the U.S. International Trade Commission in November 2021. In accordance with advice by legal counsel, the Company does not believe the verdict is legally supported and will pursue post-judgment and appellate remedies along with any other legal options available.

Contract Disputes

Alarm.com — In September 2022, Vivint Smart Home sent Alarm.com a notice asserting that it was no longer obligated to pay certain license fees under the Patent Cross License Agreement between the parties on the basis that Vivint Smart Home no longer practices any claim under any valid Alarm.com patent and, therefore, no license fees are due. Alarm.com filed an arbitration demand against Vivint Smart Home alleging, among other things, breach of the agreement due to continued use of the patents in question. The parties have resolved all outstanding litigation and entered into a long-term intellectual property licensing agreement.

STP — In July 2023, the partners in STP, CPS and Austin Energy, initiated a lawsuit and filed to intervene in the license transfer application with the NRC, claiming a right of first refusal exists in relation to the proposed sale of NRG South Texas' 44% interest in STP to Constellation. NRG believes the claims set forth by CPS and Austin Energy in the lawsuit and the NRC proceedings are without merit and intends to vigorously defend against them. For further discussion of the transaction, see Note 4, Acquisitions and Dispositions.

Winter Storm Uri Lawsuits

The Company has been named in certain property damage and wrongful death claims that have been filed in connection with Winter Storm Uri in its capacity as a generator and a REP. Most of the lawsuits related to Winter Storm Uri are consolidated into a single multi-district litigation matter in Harris County District Court. NRG's REPs have since been severed from the multi-district litigation and will be seeking dismissal in any remaining cases. As a power generator, the Company is named in various cases with claims ranging from: wrongful death; personal injury only; property damage and personal injury; property damage only; and subrogation. The First Court of Appeals conditionally granted the generators' mundamus relief, ordering the trial court to grant the generator defendents' Motions to Dismiss. The Company expected the Plaintiffs to challenge this ruling. The Company intends to vigorously defend these matters.

Indemnifications and Other Contractual Arrangements

Washington-St. Tammany and Claiborne Electric Cooperative v. LaGen — On June 28, 2017, plaintiffs Washington-St. Tammany Electric Cooperative, Inc. and Claiborne Electric Cooperative, Inc. filed a lawsuit against LaGen in the United States District Court for the Middle District of Louisiana. The plaintiffs claimed breach of contract against LaGen for allegedly improperly charging the plaintiffs for costs related to the installation and maintenance of certain pollution control technology. Plaintiffs sought damages for the alleged improper charges and a declaration as to which charges were proper under the contract. On February 4, 2019, NRG sold the South Central Portfolio, including the entities subject to this litigation. However, NRG has agreed to indemnify the purchaser for certain losses suffered in connection with this litigation. In February 2020, the federal court dismissed this lawsuit without prejudice for lack of subject matter jurisdiction. On March 17, 2020, plaintiffs filed a lawsuit in the Nineteenth Judicial District Court for the Parish of East Baton Rouge in Louisiana alleging substantially the same matters, which was dismissed on October 2, 2023 pursuant to a settlement agreement.

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Regulatory Matters

12 Months Ended

Dec. 31, 2023

Regulated Operations [Abstract]

Regulatory Matters

Regulatory Matters

NRG operates in a highly regulated industry and is subject to regulation by various federal, state and provincial agencies. As such, NRG is affected by regulatory developments at the federal, state and provincial levels and in the regions in which NRG operates.

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

California Station Power — As the result of unfavorable final and non-appealable litigation, the Company accrued a liability associated with consumption of station power at the Company's Encina power plant facility in California after August 30, 2010. The Company has established an appropriate accrual pending potential regulatory action by San Diego Gas & Electric regarding the Company's Encina facility.

Federal Trade Commission Investigation — In 2019, Vivint Smart Home received a civil investigative demand from the staff of the Federal Trade Commission (“FTC”) concerning potential violations of the Fair Credit Reporting Act and the “Red Flags Rule” thereunder, and the FTC Act. In April 2021, Vivint Smart Home entered into a settlement with the FTC that resolved this investigation. As part of this settlement, which was approved by a federal court on May 3, 2021, Vivint Smart Home paid $20 million and agreed to implement various additional compliance related measures ("Stipulated Order"). The Company is currently in the process of administering the terms of the Stipulated Order, which includes multiple undertakings by the Company. The Company is engaged in ongoing discussions with the staff of the FTC regarding the Company’s compliance with the terms of the Stipulated Order. Under the terms of the Stipulated Order, Vivint Smart Home is required to undertake biennial assessments by an independent third-party assessor (the "Assessor"), which reviews Vivint Smart Home’s compliance program and provides a report on Vivint Smart Home’s ongoing compliance with the Stipulated Order. Since its inception until December 31, 2023, Vivint Smart Home has completed its initial assessment and its first biennial assessment as required by the Stipulated Order. In addition, Vivint Smart Home has voluntarily undertaken six quarterly audits by the appointed Assessor. In all the assessments, Vivint Smart Home received a report from the Assessor with no findings of non-compliance of any kind.

New York State Public Service Commission ("NYSPSC") - Notice of Apparent Violation — The NYSPSC issued an order referred to as the Retail Reset Order in December 2019 that limited ESCO's offers for electric and natural gas to three compliant products: guaranteed savings from the utility default rate, a fixed term capped at 5% of the rolling 12-month average utility default rate, or NY-sourced renewable energy that is at least 50% greater than the prevailing NY Renewable Energy Standard for load serving entities. The order effectively limited ESCO offers to natural gas customers to only the guaranteed savings and capped fixed term compliant products because no equivalent renewable energy product exists for natural gas. NRG took action to comply with the order when it became effective April 16, 2021. On January 8, 2024, the NYSPSC notified eight of NRG's retail energy suppliers (serving both electricity and natural gas) of alleged non-compliance with New York regulatory requirements. Among other items, the notices allege that the NRG suppliers did not transition existing residential customers to one of the three compliant products authorized by the NYSPSC following the effective date of the order. NRG responded to the notices in February 2024. The outcome of this process has the potential to negatively impact the retail business in New York.

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Environmental Matters

12 Months Ended

Dec. 31, 2023

Environmental Remediation Obligations [Abstract]

Environmental Matters

Environmental Matters

NRG is subject to a wide range of environmental laws in the development, construction, ownership and operation of power plants. These laws generally require that governmental permits and approvals be obtained before construction and maintained during operation of power plants. The electric generation industry has been facing increasingly stringent requirements regarding air quality, GHG emissions, combustion byproducts, water discharge and use, and threatened and endangered species. In general, future laws are expected to require the addition of emissions controls or other environmental controls or to impose additional restrictions on the operations of the Company's facilities, which could have a material effect on the Company's consolidated financial position, results of operations, or cash flows. The Company has elected to use a $1 million disclosure threshold, as permitted, for environmental proceedings to which the government is a party.

Air

CPP/ACE Rules — In 2019, the EPA promulgated the ACE rule, which rescinded the CPP, which had sought to broadly regulate CO2 emissions from the power sector. The ACE rule required states that have coal-fired EGUs to develop plans to seek heat rate improvements from coal-fired EGUs. On January 19, 2021, the D.C. Circuit vacated the ACE rule (but on February 22, 2021, at the EPA's request, stayed the issuance of the portion of the mandate that would vacate the repeal of the CPP). On June 30, 2022, the U.S. Supreme Court held that the "generation shifting" approach in the CPP exceeded the powers granted to the EPA by Congress. The Court did not address the related issues of whether the EPA may adopt only measures applied at each source. On May 23, 2023, the EPA proposed significantly revising the manner in which new and existing EGU's GHG emissions should be regulated including using hydrogen as a fuel, capturing and storing/sequestering CO2 and requiring new units to be more efficient. The EPA has stated that it intends to finalize these revisions in 2024. The Company expects that the final rule will be challenged in the courts and accordingly uncertain over the next several years.

Cross-State Air Pollution Rule ("CSAPR") — On March 15, 2023, the EPA signed and released a prepublication of a final rule that sought to significantly revise the CSAPR to address the good-neighbor obligations of the 2015 ozone NAAQS for 23 states after earlier having disapproved numerous state plans to address the issue. Several states, including Texas, challenged the EPA's disapproval of their state plans. On May 1, 2023, the United States Court of Appeals for the Fifth Circuit stayed the EPA's disapproval of Texas' and Louisiana's state plans, which disapprovals are a condition precedent to the EPA imposing its plan on Texas and Louisiana. Several other states are also similarly situated because of similar stays. Nonetheless, on June 5, 2023, the EPA published this rule in the Federal Register. On July 31, 2023, the EPA promulgated an interim final rule that addresses the various judicial orders that have stayed several State-Implementation-Plan disapprovals by limiting the effectiveness of certain requirements of the final rule promulgated on June 5, 2023 in Texas and five other states. The final rule decreases, over time, the ozone-season NOx allowances allocated to generators in the states not affected by the judicial stays

beginning in 2023 by assuming that participants in this cap-and-trade program had or would optimize existing NOx controls and later install additional NOx controls. The Company cannot predict the outcome of the legal challenges to the: (i) various state disapprovals; (ii) the final rule promulgated on June 5, 2023; and (iii) the interim final rule promulgated on July 31, 2023 that seeks to address the judicial orders.

Regional Haze Proposal — On May 2023, the EPA proposed to withdraw the existing Texas Sulfur Dioxide Trading Program and replace it with unit-specific SO2 limits for 12 units in Texas to address requirements to improve visibility at National Parks and Wilderness areas. If finalized as proposed, the rule would result in more stringent SO2 limits for two of the Company's coal-fired units in Texas. The Company cannot predict the outcome of this proposal.

Water

Effluent Limitations Guidelines — In 2015, the EPA revised the ELG for Steam Electric Generating Facilities, which imposed more stringent requirements (as individual permits were renewed) for wastewater streams from FGD, fly ash, bottom ash, and flue gas mercury control. On September 18, 2017, the EPA promulgated a final rule that, among other things, postponed the compliance dates to preserve the status quo for FGD wastewater and bottom ash transport water by two years to November 2020 until the EPA amended the rule. On October 13, 2020, the EPA amended the 2015 ELG rule by: (i) altering the stringency of certain limits for FGD wastewater; (ii) relaxing the zero-discharge requirement for bottom ash transport water; and (iii) changing several deadlines. In October 2021, NRG informed its regulators that the Company intends to comply with the ELG by ceasing combustion of coal by the end of 2028 at its domestic coal units outside of Texas, and installing appropriate controls by the end of 2025 at its two plants that have coal-fired units in Texas. On March 29, 2023, the EPA proposed revisions to the ELG and sought comments, which the EPA is analyzing.

Byproducts

In 2015, the EPA finalized a rule regulating byproducts of coal combustion (e.g., ash and gypsum) as solid wastes under the RCRA. On August 21, 2018, the D.C. Circuit found, among other things, that the EPA had not adequately regulated unlined ponds and legacy surface impoundments. On August 28, 2020, the EPA finalized "A Holistic Approach to Close Part A: Deadline to Initiate Closure," which amended the April 2015 Rule to address the August 2018 D.C. Circuit decision and extend some of the deadlines. On November 12, 2020, the EPA finalized "A Holistic Approach to Closure Part B: Alternative Demonstration for Unlined Surface Impoundments," which further amended the April 2015 Rule to, among other things, provide procedures for requesting approval to operate existing ash impoundments with an alternative liner. On May 23, 2023, the EPA proposed establishing requirements for: (i) inactive (or legacy) surface impoundments at inactive facilities and (ii) all CCR management units (regardless of how or when the CCR was placed) at regulated facilities. NRG anticipates further rulemaking related to legacy surface impoundments and the Federal Permit Program.

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Cash Flow Information

12 Months Ended

Dec. 31, 2023

Supplemental Cash Flow Information [Abstract]

Cash Flow Information

Cash Flow Information

Detail of supplemental disclosures of cash flow and non-cash investing and financing information was:

	Year Ended December 31,
(In millions)	2023		2022		2021
Interest paid, net of amount capitalized	$	548	$	383	$	433
Income taxes paid, net of refunds	48		66		32
Non-cash investing activities:
Decreases to fixed assets for accrued capital expenditures	—		(68)		(16)

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Guarantees

12 Months Ended

Dec. 31, 2023

Guarantees [Abstract]

Guarantees

Guarantees

NRG and its subsidiaries enter into various contracts that include indemnification and guarantee provisions as a routine part of the Company's business activities. Examples of these contracts include asset purchases and sale agreements, commodity sale and purchase agreements, retail contracts, joint venture agreements, EPC agreements, operation and maintenance agreements, service agreements, settlement agreements, and other types of contractual agreements with vendors and other third parties, as well as affiliates. These contracts generally indemnify the counterparty for tax, environmental liability, litigation and other matters, as well as breaches of representations, warranties and covenants set forth in these agreements. The Company is obligated with respect to customer deposits associated with the Company's retail operations. In some cases, NRG's maximum potential liability cannot be estimated, since the underlying agreements contain no limits on potential liability.

The following table summarizes the maximum potential exposures that can be estimated for NRG's guarantees, indemnities, and other contingent liabilities by maturity:

	By Remaining Maturity at December 31,
(In millions)	2023
Guarantees	Under 1 Year		1-3 Years		3-5 Years		Over 5 Years		Total		2022 Total
Letters of credit and surety bonds	$	4,555	$	37	$	—	$	—	$	4,592	$	5,211
Asset sales guarantee obligations	13		24		22		67		126		409
Other guarantees	—		—		—		27		27		15
Total guarantees	$	4,568	$	61	$	22	$	94	$	4,745	$	5,635

Letters of credit and surety bonds — As of December 31, 2023, NRG and its consolidated subsidiaries were contingently obligated for a total of $4.6 billion under letters of credit and surety bonds. Most of these letters of credit and surety bonds are issued in support of the Company's obligations to perform under commodity agreements and obligations associated with future closure and maintenance of ash sites, as well as for financing or other arrangements. A majority of these letters of credit and surety bonds expire within one year of issuance, and it is typical for the Company to renew them on similar terms.

The material indemnities, within the scope of ASC 460, are as follows:

Asset sales — The purchase and sale agreements which govern NRG's asset or share investments and divestitures customarily contain guarantees and indemnifications of the transaction to third parties. The contracts indemnify the parties for liabilities incurred as a result of a breach of a representation or warranty by the indemnifying party, changes in tax laws or for pre-existing environmental matters. These obligations generally have a discrete term and are intended to protect the parties against risks that are difficult to predict or estimate at the time of the transaction. In several cases, the contract limits the liability of the indemnifier. NRG has no reason to believe that the Company currently has any material liability relating to such routine indemnification obligations included in the table above, except for the California property tax indemnity for estimated increases in California property taxes of certain solar properties that the Company agreed to indemnify, as part of the agreement to sell NRG Yield and the Renewables Platform. The California property tax indemnity is estimated to be $126 million as of December 31, 2023 and is included in the above table under asset sales guarantee obligations.

Other guarantees — NRG has issued other guarantees of obligations including payments under certain agreements with respect to certain of its unconsolidated subsidiaries, payment or performance by fuel providers and payment or reimbursement of credit support and deposits. The Company does not believe that it will be required to perform under these guarantees.

Other indemnities — Other indemnifications NRG has provided cover operational, tax, litigation and breaches of representations, warranties and covenants. NRG has also indemnified, on a routine basis in the ordinary course of business, consultants or other vendors who have provided services to the Company. NRG's maximum potential exposure under these indemnifications can range from a specified dollar amount to an indeterminate amount, depending on the nature of the transaction. Total maximum potential exposure under these indemnifications is not estimable due to uncertainty as to whether claims will be made or how they will be resolved. NRG does not have any reason to believe that the Company will be required to make any material payments under these indemnity provisions.

Because many of the guarantees and indemnities NRG issues to third parties and affiliates do not limit the amount or duration of its obligations to perform under them, there exists a risk that the Company may have obligations in excess of the amounts described above. For those guarantees and indemnities that do not limit the Company's liability exposure, it may not be able to estimate what the Company's liability would be, until a claim is made for payment or performance, due to the contingent nature of these contracts.

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Jointly Owned Plant

12 Months Ended

Dec. 31, 2023

Jointly Owned Plants Disclosure [Abstract]

Jointly Owned Plant

Jointly Owned Plant     

NRG owns an undivided interest in Cedar Bayou. Cedar Bayou is maintained and operated pursuant to its joint ownership participation and operating agreement. NRG is responsible for its subsidiaries' share of operating costs and direct expenses and includes its proportionate share of the facility and related revenues and direct expenses in the jointly-owned plant in the corresponding balance sheet and income statement captions of the Company's consolidated financial statements.

The following table summarizes NRG's proportionate ownership interest in the Company's jointly-owned facility:

(In millions unless otherwise stated)
As of December 31, 2023	Ownership Interest		Property, Plant & Equipment		Accumulated Depreciation		Construction in Progress
Cedar Bayou Unit 4, Baytown, TX	50.00	%	$	222	$	(115)	$	2

XML

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

12 Months Ended

Dec. 31, 2023

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS

For the Years Ended December 31, 2023, 2022 and 2021

(In millions)	Balance at Beginning of Period		Charged to Costs and Expenses		Charged to Other Accounts		Deductions			Balance at End of Period
Allowance for credit losses, deducted from accounts receivable and other non-current assets
Year Ended December 31, 2023	$	133	$	251	$	35	$	(274)	(a)	$	145
Year Ended December 31, 2022	683		11		—		(561)		(a)	133
Year Ended December 31, 2021	67		698		112		(194)		(a)	683
Income tax valuation allowance, deducted from deferred tax assets
Year Ended December 31, 2023	$	224	$	42	$	9	$	—		$	275
Year Ended December 31, 2022	248		(20)		(4)		—			224
Year Ended December 31, 2021	266		(29)		11		—			248

(a) Represents principally net amounts charged as uncollectible

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Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pay vs Performance Disclosure
Net Income (Loss)	$ (202)	$ 1,221	$ 2,187

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Insider Trading Arrangements

3 Months Ended

Dec. 31, 2023

shares

Trading Arrangements, by Individual

Material Terms of Trading Arrangement

During the three months ended December 31, 2023, the following directors or officers of the Company adopted or terminated a 'Rule 10b5-1 trading arrangement' or 'non-Rule 10b5-1 trading arrangement,' as each term is defined in Item 408(a) of Regulation S-K, as described in the table below:

Name	Title	Date Adopted	Character of Trading Arrangement	Aggregate Number of Shares of Common Stock to be Purchased or Sold Pursuant to Trading Arrangement(a)	Duration	Date Terminated
Elizabeth Killinger	Executive Vice President	12/15/2023	Rule 10b5-1 Trading Arrangement	65,583 shares to be Sold(b)	3/15/2024-1/31/2025	N/A
Rasesh Patel	Executive Vice President, Smart Home	12/15/2023	Rule 10b5-1 Trading Arrangement	Up to 73,638 shares to be Sold	3/14/2024-11/01/2024	N/A

(a)Potential sales may be subject to certain price limitations set forth in the 10b5-1 plans and therefore actual number of shares sold could vary if certain minimum stock prices are not met

(b)Represents approximate number of shares to be sold based on outstanding awards expected to vest during the period, where any underlying performance share awards are being calculated at target. Actual number of shares to be sold will depend on actual vesting, the number of shares withheld by NRG to satisfy tax withholding obligations and vesting of dividend equivalent rights

Rule 10b5-1 Arrangement Adopted

true

Non-Rule 10b5-1 Arrangement Adopted

false

Rule 10b5-1 Arrangement Terminated

false

Non-Rule 10b5-1 Arrangement Terminated

false

Elizabeth Killinger [Member]

Trading Arrangements, by Individual

Name

Elizabeth Killinger

Title

Executive Vice President

Adoption Date

12/15/2023

Arrangement Duration

322 days

Aggregate Available

65,583

Rasesh Patel [Member]

Trading Arrangements, by Individual

Name

Rasesh Patel

Title

Executive Vice President, Smart Home

Adoption Date

12/15/2023

Arrangement Duration

232 days

Aggregate Available

73,638

XML

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Basis of Presentation

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

Principles of Consolidation

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

Winter Storm Uri Uplift Securitization Proceeds

Winter Storm Uri Uplift Securitization Proceeds

The Texas Legislature passed HB 4492 in May 2021 for ERCOT to mitigate exceptionally high price adders and ancillary service costs incurred by LSEs during Winter Storm Uri. HB 4492 authorized ERCOT to obtain $2.1 billion of financing to distribute to LSEs that were charged and paid to ERCOT those highly priced ancillary service and ORDPA during Winter Storm Uri.

In December 2021, ERCOT filed with the PUCT a calculation of each LSE’s share of proceeds based on the settlement methodology. The Company accounted for the proceeds by analogy to the contribution model within ASC 958-605, Not-for-Profit Entities- Revenue Recognition and the grant model within IAS 20, Accounting for Government Grants and Disclosure of Government Assistance, as a reduction to expenses in the consolidated statements of operations in the 2021 annual period for which the proceeds were intended to compensate. The Company received proceeds of $689 million from ERCOT in June 2022.

Credit Losses

Credit Losses

In accordance with ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, or ASU No. 2016-13, retail trade receivables are reported on the balance sheet net of the allowance for credit losses within accounts receivables, net. Long-term receivables are recorded net in other non-current assets on the consolidated balance sheet. The Company accrues an allowance for current expected credit losses based on (i) estimates of uncollectible revenues by analyzing accounts receivable aging and current and reasonable forecasts of expected economic factors including, but not limited to, unemployment rates and weather-related events, (ii) historical collections and delinquencies, and (iii) counterparty credit ratings for commercial and industrial customers. The Company writes off customer contract receivable balances against the allowance for credit losses when it is determined a receivable is uncollectible.

Cash and Cash Equivalents

Cash and Cash Equivalents

Cash and cash equivalents include highly liquid investments with an original maturity of three months or less at the time of purchase.

Funds Deposited by Counterparties

Funds Deposited by Counterparties

Funds deposited by counterparties consist of cash held by the Company as a result of collateral posting obligations from its counterparties related to NRG's hedging program. The decrease in funds deposited by counterparties is driven by the significant decrease in forward positions as a result of decreases in natural gas and power prices compared to December 31, 2022. Though some amounts are segregated into separate accounts, not all funds are contractually restricted. Based on the Company's intention, these funds are not available for the payment of general corporate obligations; however, they are available for liquidity management. Depending on market fluctuations and the settlement of the underlying contracts, the Company will refund this collateral to the hedge counterparties pursuant to the terms and conditions of the underlying trades. Since collateral requirements fluctuate daily and the Company cannot predict if any collateral will be held for more than twelve months, the funds deposited by counterparties are classified as a current asset on the Company's balance sheet, with an offsetting liability for this cash collateral received within current liabilities.

Restricted Cash

Restricted Cash

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

	Year Ended December 31,
(In millions)	2023		2022		2021
Cash and cash equivalents	$	541	$	430	$	250
Funds deposited by counterparties	84		1,708		845
Restricted cash	24		40		15
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	649	$	2,178	$	1,110

Restricted cash consists primarily of funds held to satisfy the requirements of certain financing agreements and funds held within the Company's projects that are restricted in their use.

Inventory

Inventory

Inventory is valued at the lower of weighted average cost or market, and consists principally of natural gas, fuel oil, coal, spare parts and finished goods. The Company removes natural gas inventory as goods are delivered to customers and as they are used in the production of electricity or steam. The Company removes fuel oil and coal inventories as they are used in the production of electricity. The Company removes spare parts inventories when they are used for repairs, maintenance or capital projects. The Company expects to recover the natural gas, fuel oil, coal and spare parts costs in the ordinary course of business. Inventory is valued at the lower of cost or net realizable value with cost being determined on a first in first out basis for finished goods and weighted average cost method for all other inventories. The Company removes finished goods inventories as they are sold to customers. Inventories sold to customers as part of a smart home system are generally capitalized as contract costs. Sales of inventory are classified as an operating activity in the consolidated statements of cash flows.

Property, Plant and Equipment

Property, Plant and Equipment

Property, plant and equipment are stated at cost or, in the case of business acquisitions, fair value; however, impairment adjustments are recorded whenever events or changes in circumstances indicate that their carrying values may not be recoverable. Significant additions or improvements extending asset lives are capitalized as incurred, while repairs and maintenance that do not improve or extend the life of the respective asset are charged to expense as incurred. Depreciation, other than nuclear fuel, is computed using the straight-line method, while nuclear fuel was amortized based on units of production over the estimated useful lives. Certain assets and their related accumulated depreciation amounts are adjusted for asset retirements and disposals with the resulting gain or loss included in cost of operations in the consolidated statements of operations. For further discussion, see Note 9, Property, Plant and Equipment.

Business Interruption Insurance

Business Interruption Insurance

The Company carries insurance policies to cover insurable risks including, but not limited to, business interruption.

Asset Impairments

Asset Impairments

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

Investments accounted for by the equity method are reviewed for impairment in accordance with ASC 323, Investments-Equity Method and Joint Ventures, or ASC 323, which requires that a loss in value of an investment that is an other-than-temporary decline should be recognized. The Company identifies and measures losses in the value of equity method investments based upon a comparison of fair value to carrying value. For further discussion of these matters, refer to Note 11, Asset Impairments.

Debt Issuance Costs

Debt Issuance Costs

Debt issuance costs are capitalized and amortized as interest expense on a basis that approximates the effective interest method over the term of the related debt. Debt issuance costs are presented as a direct deduction from the carrying amount of the related debt, or as an asset if the issuance costs relate to revolving debt agreements or certain other financing arrangements.

Intangible Assets

Intangible Assets

Intangible assets represent contractual rights held by the Company. The Company recognizes specifically identifiable intangible assets including emissions allowances, customer and supply contracts, customer relationships, marketing partnerships, technologies, trade names and fuel contracts when specific rights and contracts are acquired. These intangible assets are amortized based on expected volumes, expected delivery, expected discounted future net cash flows, straight line or units of production basis. As of December 31, 2023 and 2022, the Company had accumulated amortization related to its intangible assets of $3.0 billion and $2.1 billion, respectively.

Emission allowances held-for-sale, which are included in other non-current assets on the Company's consolidated balance sheet, are not amortized; they are carried at the lower of cost or fair value and reviewed for impairment in accordance with ASC 360.

For further discussion, see Note 12, Goodwill and Other Intangibles.

Goodwill

Goodwill

In accordance with ASC 350, Intangibles-Goodwill and Other, or ASC 350, the Company recognizes goodwill for the excess cost of an acquired entity over the net value assigned to assets acquired and liabilities assumed. NRG performs goodwill impairment tests annually, during the fourth quarter, and when events or changes in circumstances indicate that the carrying value may not be recoverable.

The Company may first assesses qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The more-likely-than-not threshold is defined as having a likelihood of more than 50 percent. If it is not more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, there is no goodwill impairment.

In the absence of sufficient qualitative factors indicating that it is more-likely-than-not that no impairment occurred, the Company performs a quantitative assessment by determining the fair value of the reporting unit and comparing the fair value to its book value. If the fair value of the reporting unit exceeds its book value, goodwill of the reporting unit is not considered impaired. If the book value exceeds fair value, the Company recognizes an impairment loss equal to the difference between book value and fair value.

Income Taxes

Income Taxes

The Company accounts for income taxes using the liability method in accordance with ASC 740, Income Taxes, or ASC 740, which requires that the Company use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences.

The Company has two categories of income tax expense or benefit — current and deferred, as follows:

•Current income tax expense or benefit consists solely of current taxes payable less applicable tax credits, and

•Deferred income tax expense or benefit is the change in the net deferred income tax asset or liability, excluding amounts charged or credited to accumulated other comprehensive income

The Company reports some of its revenues and expenses differently for financial statement purposes than for income tax return purposes, resulting in temporary and permanent differences between the Company's financial statements and income tax returns. The tax effects of such temporary differences are recorded as either deferred income tax assets or deferred income tax liabilities in the Company's consolidated balance sheets. The Company measures its deferred income tax assets and deferred income tax liabilities using income tax rates that are expected to be in effect when the deferred tax is realized.

The Company accounts for uncertain tax positions in accordance with ASC 740, which applies to all tax positions related to income taxes. Under ASC 740, tax benefits are recognized when it is more-likely-than-not that a tax position will be sustained upon examination by the authorities. The benefit recognized from a position is the amount of benefit that has surpassed the more-likely-than-not threshold, as it is more than 50% likely to be realized upon settlement. The Company recognizes interest and penalties accrued related to uncertain tax benefits as a component of income tax expense.

In accordance with ASC 740 and as discussed further in Note 20, Income Taxes, changes to existing net deferred tax assets or valuation allowances or changes to uncertain tax benefits, are recorded to income tax (benefit)/expense.

Contract and Emission Credit Amortization

Contract and Emission Credit Amortization

Assets and liabilities recognized through acquisitions related to the purchase and sale of energy and energy-related products in future periods for which the fair value has been determined to be significantly less or more than market are amortized to revenues or cost of operations over the term of each underlying contract based on actual generation and/or contracted volumes.

Emission credits represent the right to emit a specified amount of certain pollutants, including sulfur dioxide, nitrogen oxides and carbon dioxide, over a compliance period. Emission credits held for use are amortized to cost of operations based on the weighted average cost of the allowances held.

Vivint Smart Home Flex Pay

Under the Flex Pay plan (“Flex Pay”), offered by Vivint Smart Home, subscribers pay separately for smart home products and services (smart home and security). The subscriber has the ability to pay for Vivint Smart Home products in the following three ways: (i) qualified subscribers may finance the purchase through third-party financing providers ("Consumer Financing Program" or “CFP”), (ii) Vivint Smart Home generally offers a limited number of subscribers not eligible for the CFP, but who qualify under Vivint Smart Home underwriting criteria, the option to enter into a retail installment contract directly with Vivint Smart Home or (iii) subscribers may conduct purchases by check, automatic clearing house payments, credit or debit card or by obtaining short term financing (generally no more than six-month installment terms) through Vivint Smart Home.

Although subscribers pay separately for products and services under Flex Pay, the Company has determined that the sale of products and services are one single performance obligation resulting in deferred revenue for the gross amount of products sold. For products financed through the CFP, gross deferred revenues are reduced by (i) any fees the third-party financing provider (“Financing Provider”) is contractually entitled to receive at the time of loan origination, and (ii) the present value of expected future payments due to the Financing Providers. Loans are issued on either an installment or revolving basis with repayment terms ranging from 6 to 60 months.

For certain Financing Provider loans:

•Vivint Smart Home pays a monthly fee based on either the average daily outstanding balance of the installment loans, or the number of outstanding loans.

•Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees.

•Vivint Smart Home also shares liability for credit losses, with Vivint Smart Home being responsible for between 2.6% and 100% of lost principal balances.

Due to the nature of these provisions, the Company records a derivative liability ("CFP Derivative") at its fair value when the Financing Provider originates loans to subscribers, which reduces the amount of estimated revenue recognized on the provision of the services. The derivative liability is reduced as payments are made by Vivint Smart Home to the Financing Provider. Subsequent changes to the fair value of the derivative liability are realized through other income, net in the consolidated statements of operations. For further discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities.

The Company's policies with respect to its various revenue streams are detailed below. The Company generally 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.

Retail Revenue

Gross revenues for energy sales and services to retail customers are recognized as the Company transfers the promised goods and services to the customer. Payment terms are generally 15 to 60 days. For the majority of its electricity and natural gas contracts, the Company’s performance obligation with the customer is satisfied over time and performance obligations for its electricity and natural gas products are recognized as the customer takes possession of the product. The Company also allocates the contract consideration to distinct performance obligations in a contract for which the timing of the revenue recognized is different. Additionally, customer discounts and incentives reduce the contract consideration and are recognized over the term of the contract.

Energy sales and services that have been delivered but not billed by period end are estimated. Accrued unbilled revenues are based on estimates of customer usage since the date of the last meter reading provided by the independent system operators, utilities, or electric distribution companies. Volume estimates are based on daily forecasted volumes and estimated customer usage by class. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class. Estimated amounts are adjusted when actual usage is known and billed.

As contracts for retail electricity and natural gas can be for multi-year periods, 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 that vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the amount of any unsatisfied performance obligations will vary based on customer usage, which will depend on factors such as weather and customer activity and therefore it is not practicable to estimate such amounts.

Vivint Smart Home Retail Revenue

Vivint Smart Home offers its subscribers combinations of smart home products and services, which together create an integrated smart home system that allows the Company's subscribers to monitor, control and protect their homes. As the products and services included in the subscriber's contract are integrated and highly interdependent, and because the products (including installation) and services must work together to deliver the monitoring, controlling and protection of their home, the Company has concluded that the products and services contracted for by the subscriber are generally not distinct within the context of the contract and, therefore, constitute a single, combined performance obligation. Revenues for this single, combined performance obligation are recognized on a straight-line basis over the subscriber's contract term, which is the period in which the parties to the contract have enforceable rights and obligations. The Company has determined that certain contracts that do not require a long-term commitment for monitoring services by the subscriber contain a material right to renew the contract,

because the subscriber does not have to purchase the products upon renewal. Proceeds allocated to the material right are recognized over the expected period of benefit. The majority of Vivint Smart Home's subscription contracts are five years and are generally non-cancelable. These contracts generally convert into month-to-month agreements at the end of the initial term, while some subscribers are month-to-month from inception. Payment for Vivint Smart Home services is generally due in advance on a monthly basis, with payment terms up to 30 days. Product sales and other one-time fees are invoiced to subscribers at time of sale. Revenues for any products or services that are considered separate performance obligations are recognized upon delivery. Payments received or billed in advance are reported as deferred revenues.

Energy Revenue

Both physical and financial transactions consist of revenues billed to a third-party at either market or negotiated contract terms to optimize the financial performance of the Company's generating facilities. Payment terms vary from 5 to 55 days. Electric energy revenue is recognized upon transmission to the customer over time, using the output method for measuring progress of satisfaction of performance obligations. Physical transactions, or the sale of generated electricity to meet supply and demand, are recorded on a gross basis in the Company's consolidated statements of operations. The Company applies the invoicing practical expedient in recognizing energy revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date. Financial transactions used to hedge the sale of electricity are recorded net within revenues in the consolidated statements of operations in accordance with ASC 815.

Ancillary revenues, included in Other revenue, are recognized over time as the obligation is fulfilled, using the output method for measuring progress of satisfaction of performance obligations.

Capacity Revenue

The Company's largest sources of capacity revenues are capacity auctions in PJM and NYISO. Capacity revenues also include revenues billed to a third-party at either market or negotiated contract terms for making installed generation and demand response capacity available in order to satisfy system integrity and reliability requirements. Payment terms vary from 15 to 55 days. Capacity revenues are recognized over time, using the output method for measuring progress of satisfaction of performance obligations. The Company applies the invoicing practical expedient in recognizing capacity revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date.

Gross Receipts and Sales Taxes

Gross Receipts and Sales Taxes

In connection with its retail sales, the Company records gross receipts taxes on a gross basis in revenues and cost of operations in its consolidated statements of operations. During the years ended December 31, 2023, 2022, and 2021, the Company's revenues and cost of operations included gross receipts taxes of $212 million, $218 million, and $184 million, respectively. Additionally, the Company records sales taxes collected from its taxable retail customers and remitted to the various governmental entities on a net basis; thus, there is no impact on the Company's consolidated statement of operations.

Vivint Smart Home Flex Pay

Cost of Operations

Cost of operations includes cost of fuel, purchased energy and other costs of sales, mark-to-market for economic hedging activities, contract and emission credit amortization, operations and maintenance, and other cost of operations.

Cost of Fuel, Purchased Energy and Other Cost of Sales

Cost of fuel is primarily the costs associated with procurement, transportation and storage of natural gas, nuclear fuel, oil and coal to operate the generation portfolio, which is expensed as the fuel is consumed. Purchased energy primarily relates to purchases to supply the Company's customer base, which includes spot market purchases, as well as contracts of various quantities and durations, including Renewable PPAs with third-party developers, which are primarily accounted for as NPNS (see further discussion in Derivative Instruments below). Other cost of sales primarily consists of TDSP expenses.

The cost of fuel is based on actual and estimated fuel usage for the applicable reporting period. The cost to deliver energy and related services to customers is based on actual and estimated supply volumes for the applicable reporting period. A portion of the cost of energy, $240 million, $202 million, and $189 million as of December 31, 2023, 2022, and 2021, respectively, was accrued and consisted of estimated transmission and distribution charges not yet billed by the transmission and distribution utilities.

In estimating supply volumes, the Company considers the effects of historical customer volumes, weather factors and usage by customer class. Transmission and distribution delivery fees are estimated using the same method used for electricity sales and services to retail customers. In addition, ISO fees are estimated based on historical trends, estimated supply volumes and initial ISO settlements. Volume estimates are then multiplied by the supply rate and recorded as cost of operations in the applicable reporting period.

Derivative Instruments

Derivative Instruments

The Company accounts for derivative instruments under ASC 815, which requires the Company to record all derivatives on the balance sheet at fair value and changes in fair value in earnings, unless they qualify for the NPNS exception. The Company's primary derivative instruments are power and natural gas purchase or sales contracts, fuels purchase contracts, the CFP and other energy related commodities used to mitigate variability in earnings due to fluctuation in market prices. In order to mitigate interest rate risk associated with the issuance of the Company's variable rate debt, NRG enters into interest rate swap agreements. In addition, in order to mitigate foreign exchange risk associated with the purchase of USD denominated natural gas for the Company's Canadian business, NRG enters into foreign exchange contract agreements.

As of December 31, 2023 and 2022 the Company did not have derivative instruments that were designated as cash flow or fair value hedges.

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

NRG's trading activities are subject to limits in accordance with the Company's Risk Management Policy. These contracts are recognized on the balance sheet at fair value and changes in the fair value of these derivative instruments are recognized in earnings.

Mark-to-Market for Economic Hedging Activities

NRG enters into derivative instruments to manage price and delivery risk, optimize physical and contractual assets in the portfolio and manage working capital requirements. The mark-to-market for economic hedging activities are recognized to revenues or cost of operations during the reporting period.

Operations and Maintenance and Other Costs of Operations

Operations and Maintenance and Other Cost of Operations

Operations and maintenance costs include major and other routine preventative (planned outage) and corrective (forced outage) maintenance activities to ensure the safe and reliable operation of the Company's generation portfolio in compliance

with all local, state and federal requirements. Operations and maintenance costs are also costs associated with retaining and maintaining the Company's customer base, such as call center support, portfolio maintenance and data analytics. Other cost of operations primarily includes gross receipts taxes, insurance, property taxes and asset retirement obligation expense.

Foreign Currency Translation and Transaction Gains and Losses

Foreign Currency Translation and Transaction Gains and Losses

The local currencies are generally the functional currency of NRG's foreign operations. Foreign currency denominated assets and liabilities are translated at end-of-period rates of exchange. Revenues, expenses, and cash flows are translated at the weighted-average rates of exchange for the period. The resulting currency translation adjustments are not included in the Company's consolidated statements of operations for the period, but are accumulated and reported as a separate component of stockholders' equity until sale or complete or substantially complete liquidation of the net investment in the foreign entity takes place. Foreign currency transaction gains or losses are reported within other income, net in the Company's consolidated statements of operations.

Concentrations of Credit Risk

Concentrations of Credit Risk

Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of trust funds, accounts receivable, notes receivable, derivatives and investments in debt securities. Trust funds are held in accounts managed by experienced investment advisors. Certain accounts receivable, notes receivable, and derivative instruments are concentrated within entities engaged in the energy industry. These industry concentrations may impact the Company's overall exposure to credit risk, either positively or negatively, in that the customers may be similarly affected by changes in economic, industry or other conditions. Receivables and other contractual arrangements are subject to collateral requirements under the terms of enabling agreements. However, the Company believes that the credit risk posed by industry concentration is offset by the diversification and creditworthiness of its customer base. See Note 5, Fair Value of Financial Instruments, for a further discussion of derivative concentrations.

Asset Retirement Obligations

Asset Retirement Obligations

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

Upon initial recognition of a liability for an ARO, the Company capitalizes the asset retirement cost by increasing the carrying amount of the related long-lived asset by the same amount. Over time, the liability is accreted to its future value, while the capitalized cost is depreciated over the useful life of the related asset. See Note 14, Asset Retirement Obligations, for a further discussion of AROs.

Pensions and Other Postretirement Benefits

Pensions and Other Postretirement Benefits

The Company offers pension benefits through a defined benefit pension plan. In addition, the Company provides postretirement health and welfare benefits for certain groups of employees. The Company accounts for pension and other postretirement benefits in accordance with ASC 715, Compensation — Retirement Benefits, or ASC 715. The Company recognizes the funded status of the Company's defined benefit plans in the statement of financial position and records an offset for gains and losses as well as all prior service costs that have not been included as part of the Company's net periodic benefit cost to other comprehensive income. The determination of the Company's obligation and expenses for pension benefits is dependent on the selection of certain assumptions. These assumptions determined by management include the discount rate, the expected rate of return on plan assets and the rate of future compensation increases. The Company's actuarial consultants assist in determining assumptions for such items as retirement age. The assumptions used may differ materially from actual results, which may result in a significant impact to the amount of pension obligation or expense recorded by the Company.

The Company measures the fair value of its pension assets in accordance with ASC 820, Fair Value Measurements and Disclosures, or ASC 820. For further discussion, see Note 15, Benefit Plans and Other Postretirement Benefits.

Stock-Based Compensation

Stock-Based Compensation

The Company accounts for its stock-based compensation in accordance with ASC 718, Compensation — Stock Compensation, or ASC 718. The fair value of the Company's performance stock units is estimated on the date of grant using a Monte Carlo valuation model. NRG uses the Company's common stock price on the date of grant as the fair value of the Company's deferred stock units. Forfeiture rates are estimated based on an analysis of the Company's historical forfeitures, employment turnover, and expected future behavior. The Company recognizes compensation expense for both graded and cliff

vesting awards on a straight-line basis over the requisite service period for the entire award. For further discussion, see Note 21, Stock-Based Compensation.

Investments Accounted for by the Equity Method

Investments Accounted for by the Equity Method

The Company has investments in various domestic energy projects, as well as one Australian project. The equity method of accounting is applied to such investments in affiliates, which include joint ventures and partnerships, because the ownership structure prevents the Company from exercising a controlling influence over the operating and financial policies of the projects. Under this method, equity in pre-tax income or losses of domestic partnerships and, generally, in the net income or losses of its Australian project, are reflected as equity in earnings of unconsolidated affiliates. Distributions from equity method investments that represent earnings on the Company's investment are included within cash flows from operating activities and distributions from equity method investments that represent a return of the Company's investment are included within cash flows from investing activities. For further discussion, see Note 17, Investments Accounted for by the Equity Method and Variable Interest Entities.

Sale-Leaseback Arrangements

Sale-Leaseback Arrangements

NRG is party to sale-leaseback arrangements that provide for the sale of certain assets to a third-party and simultaneously leases back the same asset to the Company. If the seller-lessee transfers control of the underlying assets to the buyer-lessor, the arrangement is accounted for under ASC 842-40, Sale-Leaseback Transactions. These arrangements are classified as operating leases on the Company's consolidated balance sheets.

Marketing and Advertising Costs

Marketing and Advertising Costs

The Company expenses its marketing and advertising costs as incurred and includes them within selling, general and administrative costs. The costs of tangible assets used in advertising campaigns are recorded as fixed assets or deferred advertising costs and amortized as advertising costs over the shorter of the useful life of the asset or the advertising campaign. The Company has several long-term sponsorship arrangements. Payments related to these arrangements are deferred and expensed over the term of the arrangement.

Business Combinations

Business Combinations

The Company accounts for its business combinations in accordance with ASC 805, Business Combinations, or ASC 805, which requires an acquirer to recognize and measure in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at fair value at the acquisition date. The Company also recognizes and measures the goodwill acquired or a gain from a bargain purchase in the business combination. In addition, transaction costs are expensed as incurred.

Use of Estimates

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.

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

Reclassifications

Reclassifications

Certain prior period amounts have been reclassified for comparative purposes. The reclassifications did not affect results from operations, net assets or cash flows.

Recent Accounting Developments

Recent Accounting Developments - Guidance Adopted in 2023

ASU 2021-08 — In October 2021, the FASB issued ASU No. 2021-08, Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers, or ASU 2021-08, which requires that an entity recognize and measure contract assets and contract liabilities acquired in a business combination as if it had originated the contracts in accordance with ASC 606, Revenue from Contracts with Customers. As a result, an acquirer should recognize and measuring the acquired contract assets and contract liabilities consistently with how they were recognized and measured in the

acquiree’s financial statements. The amendments per ASU 2021-08 apply only to contract assets and contract liabilities from contracts with customers, as defined in Topic 606, such as refund liabilities and upfront payments to customers. Assets and liabilities under related Topics, such as deferred costs under Subtopic 340-40, Other Assets and Deferred Costs — Contracts with Customers, are not within the scope of amendments per ASU 2021-08. The Company adopted ASU 2021-08 prospectively effective January 1, 2023 and applied the amended requirements to the acquisition of Vivint Smart Home.

Recent Accounting Developments - Guidance Not Yet Adopted

ASU 2023-07 – In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280) – Improvements to Reportable Segment Disclosures, or ASU 2023-07. The guidance in ASU 2023-07 enhances reportable segment disclosure requirements by requiring disclosure of significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit and loss, an amount and description of its composition for other segment items and interim disclosures of a reportable segment’s profit or loss and assets. The amendments of ASU 2023-07 are effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, with early adoption permitted and should be applied retrospectively for all prior periods presented in the financial statements. The Company is currently evaluating the impact of adopting ASU 2023-07 on its disclosures.

ASU 2023-09 – In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740) – Improvements to Income Tax Disclosures, or ASU 2023-09. The guidance in ASU 2023-09 enhances income tax disclosures by requiring disclosure of specific categories in the effective tax rate reconciliation and additional information for reconciling items that meet a quantitative threshold. Further the amendments of ASU 2023-09 require certain disclosures on income tax expense and income taxes paid. ASU 2023-09 is effective for annual periods beginning after December 15, 2024, with early adoption permitted. The amendments of ASU 2023-09 may be applied on a prospective or retrospective basis. The Company is currently evaluating the impact of adopting ASU 2023-09 on its disclosures.

Revenue Recognition

Contract and Emission Credit Amortization

Assets and liabilities recognized through acquisitions related to the purchase and sale of energy and energy-related products in future periods for which the fair value has been determined to be significantly less or more than market are amortized to revenues or cost of operations over the term of each underlying contract based on actual generation and/or contracted volumes.

Emission credits represent the right to emit a specified amount of certain pollutants, including sulfur dioxide, nitrogen oxides and carbon dioxide, over a compliance period. Emission credits held for use are amortized to cost of operations based on the weighted average cost of the allowances held.

Vivint Smart Home Flex Pay

Under the Flex Pay plan (“Flex Pay”), offered by Vivint Smart Home, subscribers pay separately for smart home products and services (smart home and security). The subscriber has the ability to pay for Vivint Smart Home products in the following three ways: (i) qualified subscribers may finance the purchase through third-party financing providers ("Consumer Financing Program" or “CFP”), (ii) Vivint Smart Home generally offers a limited number of subscribers not eligible for the CFP, but who qualify under Vivint Smart Home underwriting criteria, the option to enter into a retail installment contract directly with Vivint Smart Home or (iii) subscribers may conduct purchases by check, automatic clearing house payments, credit or debit card or by obtaining short term financing (generally no more than six-month installment terms) through Vivint Smart Home.

Although subscribers pay separately for products and services under Flex Pay, the Company has determined that the sale of products and services are one single performance obligation resulting in deferred revenue for the gross amount of products sold. For products financed through the CFP, gross deferred revenues are reduced by (i) any fees the third-party financing provider (“Financing Provider”) is contractually entitled to receive at the time of loan origination, and (ii) the present value of expected future payments due to the Financing Providers. Loans are issued on either an installment or revolving basis with repayment terms ranging from 6 to 60 months.

For certain Financing Provider loans:

•Vivint Smart Home pays a monthly fee based on either the average daily outstanding balance of the installment loans, or the number of outstanding loans.

•Vivint Smart Home incurs fees at the time of the loan origination and receives proceeds that are net of these fees.

•Vivint Smart Home also shares liability for credit losses, with Vivint Smart Home being responsible for between 2.6% and 100% of lost principal balances.

Due to the nature of these provisions, the Company records a derivative liability ("CFP Derivative") at its fair value when the Financing Provider originates loans to subscribers, which reduces the amount of estimated revenue recognized on the provision of the services. The derivative liability is reduced as payments are made by Vivint Smart Home to the Financing Provider. Subsequent changes to the fair value of the derivative liability are realized through other income, net in the consolidated statements of operations. For further discussion, see Note 6, Accounting for Derivative Instruments and Hedging Activities.

The Company's policies with respect to its various revenue streams are detailed below. The Company generally 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.

Retail Revenue

Gross revenues for energy sales and services to retail customers are recognized as the Company transfers the promised goods and services to the customer. Payment terms are generally 15 to 60 days. For the majority of its electricity and natural gas contracts, the Company’s performance obligation with the customer is satisfied over time and performance obligations for its electricity and natural gas products are recognized as the customer takes possession of the product. The Company also allocates the contract consideration to distinct performance obligations in a contract for which the timing of the revenue recognized is different. Additionally, customer discounts and incentives reduce the contract consideration and are recognized over the term of the contract.

Energy sales and services that have been delivered but not billed by period end are estimated. Accrued unbilled revenues are based on estimates of customer usage since the date of the last meter reading provided by the independent system operators, utilities, or electric distribution companies. Volume estimates are based on daily forecasted volumes and estimated customer usage by class. Unbilled revenues are calculated by multiplying these volume estimates by the applicable rate by customer class. Estimated amounts are adjusted when actual usage is known and billed.

As contracts for retail electricity and natural gas can be for multi-year periods, 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 that vary based on the contract duration, customer type, inception date and other contract-specific factors. For the fixed price contracts, the amount of any unsatisfied performance obligations will vary based on customer usage, which will depend on factors such as weather and customer activity and therefore it is not practicable to estimate such amounts.

Vivint Smart Home Retail Revenue

Vivint Smart Home offers its subscribers combinations of smart home products and services, which together create an integrated smart home system that allows the Company's subscribers to monitor, control and protect their homes. As the products and services included in the subscriber's contract are integrated and highly interdependent, and because the products (including installation) and services must work together to deliver the monitoring, controlling and protection of their home, the Company has concluded that the products and services contracted for by the subscriber are generally not distinct within the context of the contract and, therefore, constitute a single, combined performance obligation. Revenues for this single, combined performance obligation are recognized on a straight-line basis over the subscriber's contract term, which is the period in which the parties to the contract have enforceable rights and obligations. The Company has determined that certain contracts that do not require a long-term commitment for monitoring services by the subscriber contain a material right to renew the contract,

because the subscriber does not have to purchase the products upon renewal. Proceeds allocated to the material right are recognized over the expected period of benefit. The majority of Vivint Smart Home's subscription contracts are five years and are generally non-cancelable. These contracts generally convert into month-to-month agreements at the end of the initial term, while some subscribers are month-to-month from inception. Payment for Vivint Smart Home services is generally due in advance on a monthly basis, with payment terms up to 30 days. Product sales and other one-time fees are invoiced to subscribers at time of sale. Revenues for any products or services that are considered separate performance obligations are recognized upon delivery. Payments received or billed in advance are reported as deferred revenues.

Energy Revenue

Both physical and financial transactions consist of revenues billed to a third-party at either market or negotiated contract terms to optimize the financial performance of the Company's generating facilities. Payment terms vary from 5 to 55 days. Electric energy revenue is recognized upon transmission to the customer over time, using the output method for measuring progress of satisfaction of performance obligations. Physical transactions, or the sale of generated electricity to meet supply and demand, are recorded on a gross basis in the Company's consolidated statements of operations. The Company applies the invoicing practical expedient in recognizing energy revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date. Financial transactions used to hedge the sale of electricity are recorded net within revenues in the consolidated statements of operations in accordance with ASC 815.

Ancillary revenues, included in Other revenue, are recognized over time as the obligation is fulfilled, using the output method for measuring progress of satisfaction of performance obligations.

Capacity Revenue

The Company's largest sources of capacity revenues are capacity auctions in PJM and NYISO. Capacity revenues also include revenues billed to a third-party at either market or negotiated contract terms for making installed generation and demand response capacity available in order to satisfy system integrity and reliability requirements. Payment terms vary from 15 to 55 days. Capacity revenues are recognized over time, using the output method for measuring progress of satisfaction of performance obligations. The Company applies the invoicing practical expedient in recognizing capacity revenue. Under the practical expedient, revenue is recognized based on the invoiced amount which is equal to the value to the customer of NRG’s performance obligation completed to date.

Nuclear Decommissioning Policy

NRG accounted for the Nuclear Decommissioning Trust Fund in accordance with ASC 980, Regulated Operations, or ASC 980, because the Company's nuclear decommissioning activities were subject to approval by the PUCT, with regulated rates that are designed to recover all decommissioning costs and that can be charged to and collected from the ratepayers per PUCT mandate. Since the Company was in compliance with PUCT rules and regulations regarding decommissioning trusts and the cost of decommissioning was the responsibility of the Texas ratepayers, not NRG, all realized and unrealized gains or losses (including other-than-temporary impairments) related to the Nuclear Decommissioning Trust Fund were recorded to the Nuclear Decommissioning Trust liability and were not included in net income or accumulated other comprehensive income, consistent with regulatory treatment.

Following the sale of the Company's 44% equity interest in STP on November 1, 2023, the Company is no longer responsible for the decommissioning of STP and no longer holds the Nuclear Decommissioning Trust Fund assets. For further discussion of the sale, see Note 4, Acquisitions and Dispositions.

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Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2023

Accounting Policies [Abstract]

Accounts Receivable, Allowance for Credit Loss

The following table represents the activity in the allowance for credit losses for the years ended December 31, 2023, 2022, and 2021:

	Year Ended December 31,
(In millions)	2023		2022		2021
Beginning balance	$	133	$	683	$	67
Acquired balance from Vivint Smart Home	22		—		—
Acquired balance from Direct Energy	—		—		112
Provision for credit losses(a)	251		11		698
Write-offs	(313)		(593)		(224)
Recoveries collected	39		32		30
Other	13		—		—
Ending balance(a)	$	145	$	133	$	683

(a)Includes bilateral finance hedging risk of $(70) million and $403 million accounted for under ASC 815 for the years ended December 31, 2022 and December 31, 2021, respectively

Reconciliation of cash, cash equivalents, and restricted cash and cash equivalents

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

	Year Ended December 31,
(In millions)	2023		2022		2021
Cash and cash equivalents	$	541	$	430	$	250
Funds deposited by counterparties	84		1,708		845
Restricted cash	24		40		15
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	649	$	2,178	$	1,110

Detail of supplemental disclosures of cash flow and non-cash investing and financing information was:

	Year Ended December 31,
(In millions)	2023		2022		2021
Interest paid, net of amount capitalized	$	548	$	383	$	433
Income taxes paid, net of refunds	48		66		32
Non-cash investing activities:
Decreases to fixed assets for accrued capital expenditures	—		(68)		(16)

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Revenue Recognition (Tables)

12 Months Ended

Dec. 31, 2023

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following tables represent the Company’s disaggregation of revenue from contracts with customers for the years ended December 31, 2023, 2022, and 2021:

	For the Year Ended December 31, 2023
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate/Eliminations		Total
Retail revenue
Home(b)	$	6,538	$	2,195	$	1,890	$	1,549	$	(1)	$	12,171
Business	3,492		9,751		2,053		—		—		15,296
Total retail revenue(b)	10,030		11,946		3,943		1,549		(1)		27,467
Energy revenue(c)	77		291		185		—		—		553
Capacity revenue(c)	—		197		2		—		(2)		197
Mark-to-market for economic hedging activities(d)	—		57		103		—		(16)		144
Contract amortization	—		(32)		—		—		—		(32)
Other revenue(c)	369		88		48		—		(11)		494
Total revenue	10,476		12,547		4,281		1,549		(30)		28,823
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		17		35		—		—		52
Less: Realized and unrealized ASC 815 revenue	29		364		138		—		(16)		515
Total revenue from contracts with customers	$	10,447	$	12,166	$	4,108	$	1,549	$	(14)	$	28,256
(a) Includes results of operations following the acquisition date of March 10, 2023
(b) Home includes Services and Vivint Smart Home
(c) The following amounts of retail, energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home		Corporate/Eliminations		Total
Retail revenue	$	—	$	74	$	—	$	—	$	—	$	74
Energy revenue	—		162		13		—		1		176
Capacity revenue	—		73		—		—		—		73
Other revenue	29		(2)		22		—		(1)		48
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	6,388	$	2,088	$	2,286	$	(1)	$	10,761
Business	3,229		13,768		1,964		—		18,961
Total retail revenue(b)	9,617		15,856		4,250		(1)		29,722
Energy revenue(b)	111		641		466		32		1,250
Capacity revenue(b)	—		232		40		—		272
Mark-to-market for economic hedging activities(c)	2		(30)		(56)		1		(83)
Contract amortization	—		(40)		1		—		(39)
Other revenue(b)	327		104		5		(15)		421
Total revenue	10,057		16,763		4,706		17		31,543
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(7)		41		1		35
Less: Realized and unrealized ASC 815 revenue	(2)		84		(93)		31		20
Total revenue from contracts with customers	$	10,059	$	16,686	$	4,758	$	(15)	$	31,488
(a) Home includes Services
(b) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue	$	—	$	110	$	—	$	—	$	110
Energy revenue	—		(31)		(8)		31		(8)
Capacity revenue	—		33		—		—		33
Other revenue	(4)		2		(29)		(1)		(32)
(c) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Retail revenue
Home(a)	$	5,659	$	1,832	$	2,059	$	(1)	$	9,549
Business	2,745		10,030		1,237		—		14,012
Total retail revenue	8,404		11,862		3,296		(1)		23,561
Energy revenue(c)	329		508		371		7		1,215
Capacity revenue(c)	—		718		57		—		775
Mark-to-market for economic hedging activities(d)	(3)		(88)		(86)		13		(164)
Contract amortization	—		(26)		(4)		—		(30)
Other revenue(b)(c)	1,565		51		25		(9)		1,632
Total revenue	10,295		13,025		3,659		10		26,989
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	—		(25)		3		—		(22)
Less: Realized and unrealized ASC 815 revenue	130		184		(96)		16		234
Total revenue from contracts with customers	$	10,165	$	12,866	$	3,752	$	(6)	$	26,777
(a) Home includes Services
(b) Other Revenue in Texas includes ancillary revenues of $1.3 billion driven by high pricing during Winter Storm Uri
(c) The following amounts of energy, capacity and other revenue relate to derivative instruments and are accounted for under ASC 815:
(In millions)	Texas		East		West/Services/Other		Corporate/Eliminations		Total
Energy revenue	$	—	$	131	$	2	$	3	$	136
Capacity revenue	—		149		—		—		149
Other revenue	133		(8)		(12)		—		113
(d) Revenue relates entirely to unrealized gains and losses on derivative instruments accounted for under ASC 815

Contract Assets and Liabilities

The following table reflects the contract assets and liabilities included in the Company's balance sheet as of December 31, 2023 and 2022:

(In millions)	December 31, 2023		December 31, 2022
Capitalized contract costs(a)	$	706	$	126
Accounts receivable, net - Contracts with customers	3,395		4,704
Accounts receivable, net - Accounted for under topics other than ASC 606	136		64
Accounts receivable, net - Affiliate	11		5
Total accounts receivable, net	$	3,542	$	4,773
Unbilled revenues (included within Accounts receivable, net - Contracts with customers)	$	1,493	$	1,952
Deferred revenues (b)	$	1,634	$	186

(a)Amortization of capitalized contract costs for the years ended December 31, 2023, 2022 and 2021 were $168 million, $86 million and $95 million, respectively

(b)Deferred revenues from contracts with customers for the years ended December 31, 2023 and 2022 were approximately $1.6 billion and $175 million, respectively. The increase in deferred revenue balances from December 31, 2023 to 2022 was primarily due to the acquisition of Vivint Smart Home

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Acquisitions and Dispositions (Tables)

12 Months Ended

Dec. 31, 2023

Discontinued Operations and Disposal Groups [Abstract]

Schedule of Total Consideration

The total consideration of $2.623 billion includes:

	(In millions)
Vivint Smart Home, Inc. common shares outstanding as of March 10, 2023 of 216,901,639 at $12.00 per share	$	2,603
Other Vivint Smart Home, Inc. equity instruments (Cash out RSUs and PSUs, Stock Appreciation Rights, Private Placement Warrants)	6
Total Cash Consideration	$	2,609
Fair value of acquired Vivint Smart Home, Inc. equity awards attributable to pre-combination service	14
Total Consideration	$	2,623

Schedule of Purchase Price Allocation

The purchase price was allocated as follows as of December 31, 2023:

	(In millions)
Current Assets
Cash and cash equivalents	$	120
Accounts receivable, net	60
Inventory	113
Prepayments and other current assets	37
Total current assets	330
Property, plant and equipment, net	49
Other Assets
Operating lease right-of-use assets, net	35
Goodwill(a)	3,494
Intangible assets, net(b):
Customer relationships	1,740
Technology	860
Trade names	160
Sales channel contract	10
Intangible assets, net	2,770
Deferred income taxes	382
Other non-current assets	14
Total other assets	6,695
Total Assets	$	7,074
Current Liabilities
Current portion of long-term debt and finance leases	$	14
Current portion of operating lease liabilities	13
Accounts payable	109
Derivative instruments	80
Deferred revenue current	518
Accrued expenses and other current liabilities	207
Total current liabilities	941
Other Liabilities
Long-term debt and finance leases	2,572
Non-current operating lease liabilities	28
Derivative instruments	32
Deferred income taxes	18
Deferred revenue non-current	837
Other non-current liabilities	23
Total other liabilities	3,510
Total Liabilities	$	4,451
Vivint Smart Home Purchase Price	$	2,623

(a)Goodwill arising from the acquisition is attributed to the value of the platform acquired, cross-selling opportunities, subscriber growth and the synergies expected from combining the operations of Vivint Smart Home with NRG's existing businesses. None of the goodwill recorded will be deductible for tax purposes

(b)The weighted average amortization period for total amortizable intangible assets is approximately ten years

The purchase price was allocated as follows as of December 31, 2021:

	(In millions)
Current Assets
Cash and cash equivalents	$	152
Funds deposited by counterparties	21
Restricted cash	9
Accounts receivable, net	1,802
Inventory	106
Derivative instruments	1,014
Cash collateral paid in support of energy risk management activities	233
Prepayments and other current assets	173
Total current assets	3,510
Property, plant and equipment, net	151
Other Assets
Goodwill(a)	1,250
Intangible assets, net:
Customer relationships(b)	1,277
Customer and supply contracts(b)	610
Trade names(b)	310
Renewable energy credits	124
Total intangible assets, net	2,321
Derivative instruments	531
Other non-current assets	31
Total other assets	4,133
Total Assets	$	7,794
Current Liabilities
Accounts payable	$	1,116
Derivative instruments	1,266
Cash collateral received in support of energy risk management activities	21
Accrued expenses and other current liabilities	670
Total current liabilities	3,073
Other Liabilities
Derivative instruments	562
Deferred income taxes	320
Other non-current liabilities	115
Total other liabilities	997
Total Liabilities	$	4,070
Direct Energy Purchase Price	$	3,724

(a)Goodwill arising from the acquisition was attributed to the value of the platform acquired and the synergies expected from combining the operations of Direct Energy with NRG's existing businesses. Goodwill was allocated to the Texas, East, and West/Services/Other segments of $427 million, $648 million and $175 million, respectively. Goodwill deductible for tax purposes was $322 million

(b)As of January 5, 2021, the weighted average amortization period for total amortizable intangible assets was 12 years

Schedule of Pro Forma Financial Information

The pro forma financial information has been prepared for illustrative and informational purposes only, and is not intended to project future operating results or be indicative of what the Company's financial performance would have been had the transactions occurred on the date indicated. No effect has been given to prospective operating synergies.

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Total operating revenues	$	29,109	$	33,225	$	28,468
Net (loss)/income	(3)		1,136		1,574

Summary of Results of Discontinued Operations

The Company recorded income before income taxes from its 44% equity interest in STP as follows:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Income before income taxes(a)	$	206	$	362	$	829

(a)Excludes the impact of the Company's hedges at the portfolio level

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Fair Value of Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2023

Fair Value Disclosures [Abstract]

Estimated Carrying Amounts and Fair Values of Financial Instruments Not Carried at Fair Value

The estimated carrying value and fair value of the Company's long-term debt, including current portion, is as follows:

	As of December 31,
	2023				2022
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Convertible Senior Notes	$	575	$	739	$	575	$	576
Other long-term debt, including current portion	10,219		9,835		7,523		6,432
Total long-term debt, including current portion(a)	$	10,794	$	10,574	$	8,098	$	7,008

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

Assets and Liabilities Measured and Recorded at Fair Value Measured on a Recurring Basis

The following tables present assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy:

	As of December 31, 2023
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	21	$	—	$	21	$	—
Derivative assets:
Interest rate contracts	12		—		12		—
Foreign exchange contracts	5		—		5		—
Commodity contracts	6,138		1,334		4,470		334
Equity securities measured using net asset value practical expedient (classified within other non-current assets)	6
Total assets	$	6,182	$	1,334	$	4,508	$	334
Derivative liabilities:
Interest rate contracts	$	8	$	—	$	8	$	—
Foreign exchange contracts	9		—		9		—
Commodity contracts	5,356		1,413		3,728		215
Consumer Financing Program	134		—		—		134
Total liabilities	$	5,507	$	1,413	$	3,745	$	349

	As of December 31, 2022
	Fair Value
(In millions)	Total		Level 1		Level 2		Level 3
Investments in securities (classified within other current and non-current assets)	$	19	$	—	$	19	$	—
Nuclear trust fund investments:
Cash and cash equivalents	15		15		—		—
U.S. government and federal agency obligations	86		84		2		—
Federal agency mortgage-backed securities	101		—		101		—
Commercial mortgage-backed securities	35		—		35		—
Corporate debt securities	114		—		114		—
Equity securities	403		403		—		—
Foreign government fixed income securities	1		—		1		—
Other trust fund investments (classified within other non-current assets):
U.S. government and federal agency obligations	1		1		—		—
Derivative assets:
Foreign exchange contracts	18		—		18		—
Commodity contracts	11,976		1,929		8,796		1,251
Measured using net asset value practical expedient:
Equity securities - nuclear trust fund investments	83
Equity securities (classified within other non-current assets)	6
Total assets	$	12,858	$	2,432	$	9,086	$	1,251
Derivative liabilities:
Foreign exchange contracts	$	2	$	—	$	2	$	—
Commodity contracts	8,439		1,244		6,449		746
Total liabilities	$	8,441	$	1,244	$	6,451	$	746

Reconciliation of Beginning and Ending Balances for Financial Instruments that are Recognized at Fair Value using Significant Unobservable Inputs

The following table reconciles, for the years ended December 31, 2023 and 2022, the beginning and ending balances for financial instruments that are recognized at fair value in the consolidated financial statements using significant unobservable inputs, for commodity derivatives:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Commodity Derivatives (a)
	For the Year Ended December 31,
(In millions)	2023		2022
Beginning balance	$	505	$	293
Total (losses)/gains realized/unrealized included in earnings	(164)		53
Purchases	42		(110)
Transfers into Level 3(b)	78		264
Transfers out of Level 3(b)(c)	(342)		5
Ending balance	$	119	$	505
(Losses)/gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of year-end	$	(46)	$	204

(a)Consists of derivatives assets and liabilities, net, excluding derivative liabilities from Consumer Financing Program, which are presented in a separate table below

(b)Transfers into/out of Level 3 are related to the availability of consensus pricing and external broker quotes, and are valued as of the end of the reporting period. All transfers into/out of Level 3 are from/to Level 2

(c)For the year ended December 31, 2023, due to the change to use consensus pricing, there was a decrease in the number of contracts valued with prices provided by models and other valuation techniques, which resulted in a large transfer out of Level 3

Reconciliation of Contractual Obligations of Consumer Financing Program Recognized at Fair Value

The following table reconciles, for the year ended December 31, 2023, the beginning and ending balances of the contractual obligations from the Consumer Financing Program that are recognized at fair value in the condensed consolidated financial statements, using significant unobservable inputs:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Consumer Financing Program
(In millions)	For the Year Ended December 31, 2023
Beginning balance	$	—
Contractual obligations added from the acquisition of Vivint Smart Home	(112)
New contractual obligations	(68)
Settlements	62
Total losses included in earnings	(16)
Ending balance	$	(134)

Schedule of Significant Unobservable Inputs used in Developing Fair Value of Level 3 Positions

The following tables quantify the significant unobservable inputs used in developing the fair value of the Company's Level 3 positions as of December 31, 2023 and 2022:

	Significant Unobservable Inputs
	December 31, 2023
	Fair Value						Input/Range
(in millions, except as noted)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low			High			Weighted Average
Natural Gas Contracts	$	39	$	65	Discounted Cash Flow	Forward Market Price ($ per MMBtu)	$	1		$	15		$	3
Power Contracts	197		66		Discounted Cash Flow	Forward Market Price ($ per MWh)	1			210			47
Capacity Contracts	21		33		Discounted Cash Flow	Forward Market Price ($ per MW/Day)	49			658			285
Renewable Energy Certificates	58		14		Discounted Cash Flow	Forward Market Price ($ per Certificate)	2			320			15
FTRs	19		37		Discounted Cash Flow	Auction Prices ($ per MWh)	(58)			252			0
Consumer Financing Program	—		134		Discounted Cash Flow	Collateral Default Rates	0.43		%	93.30		%	8.12		%
					Discounted Cash Flow	Collateral Prepayment Rates	2.00		%	3.00		%	2.95		%
					Discounted Cash Flow	Credit Loss Rates	6.00		%	60.00		%	12.57		%
	$	334	$	349

	Significant Unobservable Inputs
	December 31, 2022
	Fair Value						Input/Range
(in millions, except as noted)	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
Natural Gas Contracts	$	340	$	448	Discounted Cash Flow	Forward Market Price ($ per MMBtu)	$	2	$	48	$	6
Power Contracts	843		216		Discounted Cash Flow	Forward Market Price ($ per MWh)	3		431		48
FTRs	68		82		Discounted Cash Flow	Auction Prices ($ per MWh)	(32)		610		0
	$	1,251	$	746

Fair Value Inputs, Sensitivity Analysis

The following table provides sensitivity of fair value measurements to increases/(decreases) in significant unobservable inputs as of December 31, 2023 and 2022:

Significant Unobservable Input	Position	Change In Input	Impact on Fair Value Measurement
Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates	Buy	Increase/(Decrease)	Higher/(Lower)
Forward Market Price Natural Gas/Power/Capacity/Renewable Energy Certificates	Sell	Increase/(Decrease)	Lower/(Higher)
FTR Prices	Buy	Increase/(Decrease)	Higher/(Lower)
FTR Prices	Sell	Increase/(Decrease)	Lower/(Higher)
Collateral Default Rates	n/a	Increase/(Decrease)	Higher/(Lower)
Collateral Prepayment Rates	n/a	Increase/(Decrease)	Lower/(Higher)
Credit Loss Rates	n/a	Increase/(Decrease)	Higher/(Lower)

Net Counterparty Credit Exposure by Industry Sector and by Counterparty Credit Quality

The following tables highlight net counterparty credit exposure by industry sector and by counterparty credit quality. Net counterparty credit exposure is defined as the aggregate net asset position for NRG with counterparties where netting is permitted under the enabling agreement and includes all cash flow, mark-to-market and NPNS, and non-derivative transactions. The exposure is shown net of collateral held and includes amounts net of receivables or payables.

Category	Net Exposure (a) (b) (% of Total)
Utilities, energy merchants, marketers and other	80	%
Financial institutions	20
Total	100	%

Category	Net Exposure (a) (b) (% of Total)
Investment grade	44	%
Non-Investment grade/Non-Rated	56
Total	100	%

(a)Counterparty credit exposure excludes coal transportation contracts because of the unavailability of market prices

(b)The figures in the tables above exclude potential counterparty credit exposure related to RTOs, ISOs, registered commodity exchanges and certain long term contracts

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Accounting for Derivative Instruments and Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Net Notional Volume Buy/(sell) of NRG's Open Derivative Transactions Broken Out By Commodity

The following table summarizes the net notional volume buy/(sell) of NRG's open derivative transactions broken out by commodity, excluding those derivatives that qualified for the NPNS exception as of December 31, 2023 and 2022. Option contracts are reflected using delta volume. Delta volume equals the notional volume of an option adjusted for the probability that the option will be in-the-money at its expiration date.

		Total Volume (In millions)
Category	Units	December 31, 2023	December 31, 2022
Emissions	Short Ton	—	1
Renewables Energy Certificates	Certificates	12	15
Coal	Short Ton	9	11
Natural Gas	MMBtu	838	422
Oil	Barrels	—	1
Power	MWh	201	192
Interest	Dollars	1,000	—
Foreign Exchange	Dollars	548	569
Consumer Financing Program	Dollars	1,116	—

Fair Value Within the Derivative Instrument Valuation On the Balance Sheet

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

	Fair Value
	Derivative Assets				Derivative Liabilities
(In millions)	December 31, 2023		December 31, 2022		December 31, 2023		December 31, 2022
Derivatives Not Designated as Cash Flow or Fair Value Hedges:
Interest rate contracts - current	$	12	$	—	$	—	$	—
Interest rate contracts - long-term	—		—		8		—
Foreign exchange contracts - current	3		11		4		1
Foreign exchange contracts - long-term	2		7		5		1
Commodity contracts- current	3,847		7,875		3,922		6,194
Commodity contracts- long-term	2,291		4,101		1,434		2,245
Consumer Financing Program - current	—		—		93		—
Consumer Financing Program - long-term	—		—		41		—
Total Derivatives Not Designated as Cash Flow or Fair Value Hedges	$	6,155	$	11,994	$	5,507	$	8,441

Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received Or Paid

The following table summarizes the offsetting derivatives by counterparty master agreement level and collateral received or paid:

	Gross Amounts Not Offset in the Statement of Financial Position
(In millions)	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Cash Collateral (Held)/Posted		Net Amount
As of December 31, 2023
Interest rate contracts:
Derivative assets	$	12	$	(8)	$	—	$	4
Derivative liabilities	(8)		8		—		—
Total interest rate contracts	4		—		—		4
Foreign exchange contracts:
Derivative assets	$	5	$	(5)	$	—	$	—
Derivative liabilities	(9)		5		—		(4)
Total foreign exchange contracts	$	(4)	$	—	$	—	$	(4)
Commodity contracts:
Derivative assets	$	6,138	$	(4,926)	$	(74)	$	1,138
Derivative liabilities	(5,356)		4,926		145		(285)
Total commodity contracts	$	782	$	—	$	71	$	853
Consumer Financing Program:
Derivative liabilities	$	(134)	$	—	$	—	$	(134)
Total derivative instruments	$	648	$	—	$	71	$	719

	Gross Amounts Not Offset in the Statement of Financial Position
(In millions)	Gross Amounts of Recognized Assets/Liabilities		Derivative Instruments		Cash Collateral (Held)/Posted		Net Amount
As of December 31, 2022
Foreign exchange contracts:
Derivative assets	$	18	$	(2)	$	—	$	16
Derivative liabilities	(2)		2		—		—
Total foreign exchange contracts	$	16	$	—	$	—	$	16
Commodity contracts:
Derivative assets	$	11,976	$	(7,897)	$	(1,659)	$	2,420
Derivative liabilities	(8,439)		7,897		20		(522)
Total commodity contracts	$	3,537	$	—	$	(1,639)	$	1,898
Total derivative instruments	$	3,553	$	—	$	(1,639)	$	1,914

Pre-tax Effects of Economic Hedges That Have Not Been Designated As Cash Flow Hedges, Ineffectiveness On Cash Flow Hedges And Trading Activity on the Company's Statement of Operations

The following table summarizes the pre-tax effects of economic hedges that have not been designated as cash flow hedges or fair value hedges and trading activity on the Company's statement of operations. The effect of foreign exchange and commodity hedges is included within revenues and cost of operations. The effect of the interest rate contracts are included within interest expense. The effect of the Consumer Financing Program is included in other income, net.

	Year Ended December 31,
(In millions)	2023		2022		2021
Unrealized mark-to-market results
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$	(1,734)	$	(1,232)	$	(41)
Reversal of acquired loss positions related to economic hedges	20		2		256
Net unrealized (losses)/gains on open positions related to economic hedges	(1,149)		2,478		2,501
Total unrealized mark-to-market (losses)/gains for economic hedging activities	(2,863)		1,248		2,716
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	13		13		(18)
Reversal of acquired (gain) positions related to trading activity	—		—		(1)
Net unrealized gains/(losses) on open positions related to trading activity	25		(17)		(13)
Total unrealized mark-to-market gains/(losses) for trading activity	38		(4)		(32)
Total unrealized (losses)/gains - commodities and foreign exchange	$	(2,825)	$	1,244	$	2,684

	Year Ended December 31,
(In millions)	2023		2022		2021
Total impact to statement of operations - interest rate contracts	$	4	$	—	$	—
Unrealized gains/(losses) included in revenues - commodities	$	182	$	(87)	$	(196)
Unrealized (losses)/gains included in cost of operations - commodities	(2,988)		1,315		2,880
Unrealized (losses)/gains included in cost of operations - foreign exchange	(19)		16		—
Total impact to statement of operations - commodities and foreign exchange	$	(2,825)	$	1,244	$	2,684
Total impact to statement of operations - Consumer Financing Program	$	(16)	$	—	$	—

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Nuclear Decommissioning Trust Fund (Tables)

12 Months Ended

Dec. 31, 2023

Regulated Operations [Abstract]

Summary of Aggregate Fair Values and Unrealized Gains And Losses (Including Other-Than-Temporary Impairments) for the Securities Held in The Nuclear Decommissioning Trust Fund

The following table summarizes the aggregate fair values and unrealized gains and losses for the securities held in the trust funds as of December 31, 2022, as well as information about the contractual maturities of those securities as of that date.

	As of December 31, 2022
(In millions, except otherwise noted)	Fair Value		Unrealized Gains		Unrealized Losses		Weighted- average maturities (in years)
Cash and cash equivalents	$	15	$	—	$	—	—
U.S. government and federal agency obligations	86		—		5		11
Federal agency mortgage-backed securities	101		—		11		26
Commercial mortgage-backed securities	35		—		4		30
Corporate debt securities	114		—		13		12
Equity securities	486		346		3		—
Foreign government fixed income securities	1		—		—		17
Total	$	838	$	346	$	36

Summary of Proceeds From Sales of Available-For-Sale securities and the related realized gains and losses

The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from these sales for the ten months ended October 31, 2023, and for the years ended December 31, 2022 and 2021. The cost of securities sold was determined using the specific identification method.

(In millions)	2023		2022		2021
Realized gains	$	11	$	14	$	47
Realized losses	(19)		(25)		(9)
Proceeds from sale of securities	355		448		710

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Inventory (Tables)

12 Months Ended

Dec. 31, 2023

Inventory Disclosure [Abstract]

Schedule of Inventory

Inventory consisted of:

	As of December 31,
(In millions)	2023		2022
Fuel oil	$	8	$	8
Coal	178		114
Natural gas	189		385
Spare parts	68		136
Finished goods	164		108
Total Inventory	$	607	$	751

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Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2023

Property, Plant and Equipment [Abstract]

Major Classes of Property, Plant and Equipment

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

	As of December 31,				Depreciable
(In millions)	2023		2022		Lives
Facilities and equipment	$	1,918	$	1,727	1-40 years
Land and improvements	256		263
Nuclear fuel	—		271		5 years
Hardware and office equipment and furnishings	732		712		2-10 years
Construction in progress	152		197
Total property, plant, and equipment	3,058		3,170
Accumulated depreciation	(1,295)		(1,478)
Net property, plant, and equipment	$	1,763	$	1,692

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Leases (Tables)

12 Months Ended

Dec. 31, 2023

Leases [Abstract]

Lease Cost

Lease Cost:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Finance lease cost	$	8	$	4	$	4
Amortization of right-of-use assets	7		4		4
Interest on lease liabilities	1		—		—
Operating lease cost	93		85		91
Short-term lease cost	42		7		3
Variable lease cost	91		86		9
Sublease income	(2)		(2)		(2)
Total lease cost	$	232	$	180	$	105

Other information:

	For the Year Ended December 31,
(In millions)	2023		2022		2021
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	195	$	183	$	102
Financing cash flows from finance leases	7		5		6
Right-of-use assets obtained in exchange for new finance lease liabilities	17		3		16
Right-of-use assets obtained in exchange for new operating lease liabilities	52		28		47

Lease Term and Discount Rate for leases:

	December 31, 2023		December 31, 2022
Finance leases:
Weighted average remaining lease term (in years)	2.9		2.6
Weighted average discount rate	4.87	%	2.82	%
Operating leases:
Weighted average remaining lease term (in years)	3.6		4.3
Weighted average discount rate	6.00	%	5.37	%

Schedule of Annual Payments Based on Maturities of Leases

As of December 31, 2023, annual payments based on the maturities of the Company's operating leases are expected to be as follows:

	In millions
2024	$	118
2025	86
2026	34
2027	24
2028	17
Thereafter	32
Total undiscounted lease payments	$	311
Less: present value adjustment	(93)
Total discounted lease payments	$	218

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Goodwill and Other Intangibles (Tables)

12 Months Ended

Dec. 31, 2023

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

The table below presents the changes of goodwill for the years ended December 31, 2023 and 2022 based on the Company's reportable segments.

(in millions)	Texas		East		West/Services/Other		Vivint Smart Home		Total
Balance as of January 1, 2022	$	716	$	853	$	226	$	—	$	1,795
Impairment losses	—		(130)		—		—		(130)
Asset sales	(6)		—		—		—		(6)
Foreign currency translation	—		—		(9)		—		(9)
Balance as of December 31, 2022	$	710	$	723	$	217	$	—	$	1,650
Goodwill resulted from the acquisition of Vivint	—		—		—		3,494		3,494
Asset sales	(67)		(2)		—		—		(69)
Foreign currency translation	—		—		4		—		4
Balance as of December 31, 2023	$	643	$	721	$	221	$	3,494	$	5,079

Summary of the Components of Intangible Assets Subject to Amortization

The following tables summarize the components of NRG's intangible assets:

(In millions)
Year Ended December 31, 2023	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Technology		Trade Names		Other(a)		Total
January 1, 2023	$	624	$	635	$	1,730	$	284	$	—	$	679	$	292	$	4,244
Purchases	10		—		—		—		—		—		465		475
Acquisition of businesses(b)	—		—		1,773		10		860		160		—		2,803
Usage/Sales/Retirements	—		—		—		—		—		—		(474)		(474)
Write-off of fully amortized balances	(1)		(28)		(43)		—		—		—		—		(72)
Sale of STP(c)	—		—		—		—		—		—		(59)		(59)
Other	(5)		2		4		1		—		2		—		4
December 31, 2023	628		609		3,464		295		860		841		224		6,921
Less accumulated amortization	(533)		(328)		(1,300)		(170)		(230)		(401)		(32)		(2,994)
Net carrying amount	$	95	$	281	$	2,164	$	125	$	630	$	440	$	192	$	3,927

(a)RECs are not subject to amortization and had a carrying value of $177 million

(b)The weighted average amortization period for total amortizable intangible assets is approximately 10 years. See Note 4, Acquisitions and Dispositions, for weighted average life of acquired amortizable intangibles for each intangible asset type

(c)Includes $47 million of intangibles that were amortized

(In millions)
Year Ended December 31, 2022	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Trade Names		Other(a)		Total
January 1, 2022	$	634	$	638	$	1,679	$	284	$	683	$	229	$	4,147
Purchases	26		—		—		—		—		404		430
Acquisition of businesses(b)	—		—		55		—		—		—		55
Usage/Retirements	(33)		—		—		—		—		(341)		(374)
Write-off of fully amortized balances	(14)		—		—		—		—		—		(14)
Other	11		(3)		(4)		—		(4)		—		—
December 31, 2022	624		635		1,730		284		679		292		4,244
Less accumulated amortization	(528)		(235)		(787)		(146)		(341)		(75)		(2,112)
Net carrying amount	$	96	$	400	$	943	$	138	$	338	$	217	$	2,132

(a)RECs are not subject to amortization and had a carrying value of $186 million

(b)The weighted average life of acquired amortizable intangibles was six years for customer relationships

Schedule of Amortization and Retirements of Intangible Expense

The following table presents NRG's amortization of intangible assets for each of the past three years:

	Years Ended December 31,
(In millions)	2023		2022		2021
Emission allowances	$	6	$	6	$	24
Customer and supply contracts	121		141		66
Customer relationships	556		269		327
Marketing partnerships	24		23		24
Technology	230		—		—
Trade names	60		47		47
Other(a)	4		4		7
Total amortization	$	1,001	$	490	$	495

(a)For the year ended December 31, 2023, 2022 and 2021, other intangibles amortized to depreciation and amortization expense were de minimis, $4 million and $3 million, respectively

Schedule of Estimated Amortization of Intangible Assets for Next Five Years

The following table presents estimated amortization of NRG's intangible assets as of December 31, 2023 for each of the next five years:

(In millions)
Year Ended December 31,	Emission Allowances		Customer and Supply Contracts		Customer Relationships		Marketing Partnerships		Technology		Trade Names		Other		Total
2024	$	17	$	73	$	478	$	24	$	227	$	54	$	3	$	876
2025	14		50		371		23		176		47		3		684
2026	9		52		300		23		130		39		3		556
2027	8		30		233		23		89		39		3		425
2028	9		13		189		15		9		39		2		276

XML

Long-term Debt and Finance Leases (Tables)

12 Months Ended

Dec. 31, 2023

Debt Disclosure [Abstract]

Long-term Debt and Finance Leases

Long-term debt and finance leases consisted of the following:

	As of December 31,
(In millions, except rates)	2023		2022		Interest rate %
Recourse debt:
Senior Notes, due 2027	$	375	$	375	6.625
Senior Notes, due 2028	821		821		5.750
Senior Notes, due 2029	733		733		5.250
Senior Notes, due 2029	500		500		3.375
Senior Notes, due 2031	1,030		1,030		3.625
Senior Notes, due 2032	480		1,100		3.875
Convertible Senior Notes, due 2048(a)	575		575		2.750
Senior Secured First Lien Notes, due 2024	600		600		3.750
Senior Secured First Lien Notes, due 2025	500		500		2.000
Senior Secured First Lien Notes, due 2027	900		900		2.450
Senior Secured First Lien Notes, due 2029	500		500		4.450
Senior Secured First Lien Notes, due 2033	740		—		7.000
Tax-exempt bonds	466		466		1.250 - 4.750
Subtotal recourse debt	8,220		8,100
Non-recourse debt:
Vivint Smart Home Senior Notes, due 2029	800		—		5.750
Vivint Smart Home Senior Secured Notes, due 2027	600		—		6.750
Vivint Smart Home Senior Secured Term Loan, due 2028	1,320		—		SOFR + 3.51
Subtotal all non-recourse debt	2,720		—
Subtotal long-term debt (including current maturities)	10,940		8,100
Finance leases	19		11		various
Subtotal long-term debt and finance leases (including current maturities)	10,959		8,111
Less current maturities	(620)		(63)
Less debt issuance costs	(60)		(70)
Discounts	(146)		(2)
Total long-term debt and finance leases	$	10,133	$	7,976

(a)As of the ex-dividend date of January 31, 2024, the Convertible Senior Notes were convertible at a price of $41.53, which is equivalent to a conversion rate of approximately 24.0763 shares of common stock per $1,000 principal amount

Debt includes the following discounts:

	As of December 31,
(In millions)	2023		2022
Senior Secured First Lien Notes, due 2024, 2025, 2027, 2029 and 2033	$	(10)	$	(2)
Vivint Smart Home Senior Notes, due 2029	(103)		—
Vivint Smart Home Senior Secured Notes, due 2027	(12)		—
Vivint Smart Home Senior Secured Term Loan, due 2028	(21)		—
Total discounts	$	(146)	$	(2)

Consolidated Annual Maturities

As of December 31, 2023, annual payments based on the maturities of NRG's debt and finance leases are expected to be as follows:

	(In millions)
2024	$	620
2025	769
2026	16
2027	1,890
2028	2,145
Thereafter	5,519
Total	$	10,959

Recourse Debt

Revolving Credit Facility

On February 14, 2023 (the “Revolving Credit Facility Sixth Amendment Effective Date”), the Company amended its Revolving Credit Facility to: (i) increase the existing revolving commitments thereunder by $600 million (the “Initial Incremental Commitment”), (ii) extend the maturity date of a portion of the revolving commitments thereunder to February 14, 2028, (iii) transition the benchmark rate applicable to revolving loans from LIBOR to SOFR and (iv) make certain other amendments to the terms of the Revolving Credit Facility for purposes of, among other things, providing additional flexibility.

On March 13, 2023 (the “Revolving Credit Facility Seventh Amendment Effective Date”), the Company further amended its Revolving Credit Facility to increase the existing revolving commitments by an additional $45 million (together with the Initial Incremental Commitment, the "Incremental Commitment").

After giving effect to the Incremental Commitment, the Company had a total of $4.305 billion of revolving commitments available under the Revolving Credit Facility. The full amount of the Initial Incremental Commitment was made available from and after the Revolving Credit Facility Sixth Amendment Effective Date and the full amount of the Incremental Commitment was made available from and after the Revolving Credit Facility Seventh Amendment Effective Date. A portion of the non-extended revolving commitments terminated on July 5, 2023, with the remaining portion thereof terminating on May 28, 2024, unless otherwise extended.

The Revolving Credit Facility is guaranteed by NRG’s existing and future direct and indirect subsidiaries, with customary and agreed-upon exceptions for, among other exceptions, unrestricted subsidiaries, foreign subsidiaries, project subsidiaries, immaterial subsidiaries, captive insurance subsidiaries and securitization vehicles. The Revolving Credit Facility is also secured by a first priority (subject to certain customary permitted liens) perfected security interest in a substantial portion of the property and assets owned by NRG and its subsidiaries that are guarantors under the Revolving Credit Facility, subject to certain exceptions that include, among other things, the capital stock of certain specified subsidiaries, including unrestricted subsidiaries and certain excluded subsidiaries, equity interests in excess of 66% of the total outstanding voting equity interests of certain foreign subsidiaries, equity interests the pledge of which is prohibited by applicable agreements binding on such subsidiaries and other assets that may be designated by NRG as excluded from the collateral that, when taken together with all other assets so designated since the Revolving Credit Facility Sixth Amendment Effective Date, have an aggregate fair market value not exceeding $750 million. The Revolving Credit Facility is secured on a pari passu basis with certain interest rate, foreign currency and commodity hedging obligations of NRG, the Senior Secured First Lien Notes and certain other indebtedness. The collateral securing the Revolving Credit Facility will be released at the Company's request if both the senior unsecured long-term debt securities of the Company and the revolving loans under the Revolving Credit Facility are rated investment grade by any two of the three rating agencies and the satisfaction of certain other conditions, subject to reversion if such rating agencies withdraw such investment grade rating or downgrade such rating below investment grade (or, with respect to the revolving loans, crease to publish a rating).

The Revolving Credit Facility contains customary covenants, which, among other things, require NRG to maintain a maximum first lien leverage ratio on a consolidated basis when amounts outstanding under the Revolving Credit Facility (subject to certain exceptions) exceed a certain threshold and limit, subject to certain exceptions, NRG’s ability to:

•incur indebtedness and liens and enter into sale and lease-back transactions;

•make investments, loans and advances;

•return capital to shareholders;

•repay material subordinated indebtedness;

•consummate mergers, consolidations and asset sales;

•enter into affiliate transactions; and

•change its fiscal year-end.

As of December 31, 2023, there were no outstanding borrowings and there were $883 million in letters of credit issued under the Revolving Credit Facility.

Senior Notes

Issuance of 2033 Senior Secured First Lien Notes

On March 9, 2023, the Company issued $740 million of aggregate principal amount of 7.000% senior secured first lien notes due 2033 (the "2033 Senior Secured First Lien Notes"). The 2033 Senior Secured First Lien Notes are senior secured obligations of NRG and are guaranteed by certain of its subsidiaries that guarantee indebtedness under the Revolving Credit Facility. The 2033 Senior Secured First Lien Notes are secured by a first priority security interest in the same collateral that is pledged for the benefit of the lenders under the Revolving Credit Facility, which collateral consists of a substantial portion of the property and assets owned by the Company and the guarantors. The collateral securing the 2033 Senior Secured First Lien Notes will be released at the Company’s request if the senior unsecured long-term debt securities of the Company are rated investment grade by any two of the three rating agencies and the satisfaction of certain other conditions, subject to reversion if such rating agencies withdraw such investment grade rating or downgrade such rating below investment grade. Interest is paid semi-annually beginning on September 15, 2023 until the maturity date of March 15, 2033. The proceeds of the 2033 Senior Secured First Lien Notes, along with cash on hand and proceeds from certain other financings, were used to fund the acquisition of Vivint Smart Home.

Senior Note Redemptions

During the year ended December 31, 2023, the Company redeemed $620 million in aggregate principal amount of its 3.875% Senior Notes, due 2032, for $509 million, which included the payment of $7 million of accrued interest, using cash on hand at an average early redemption percentage of 81%. In connection with the redemption, a $109 million gain on debt extinguishment was recorded, which included the write-off of previously deferred financing costs and other fees of $9 million.

During the year ended December 31, 2021, the Company redeemed approximately $1.9 billion in aggregate principal amount of its Senior Notes for $1.9 billion using the proceeds of the 2032 Senior Notes and cash on hand, as detailed in the table below. In connection with the redemptions, a $77 million loss on debt extinguishment was recorded, which included the write-off of previously deferred financing costs of $12 million.

(In millions, except percentages)	Principal Repurchased		Cash Paid(a)		Average Early Redemption Percentage
7.250% Senior Notes, due 2026	$	1,000	$	1,056	103.625	%
6.625% Senior Notes, due 2027	855		893		103.313	%
Total	$	1,855	$	1,949

(a)Includes accrued interest of $29 million for redemptions for the year ended December 31, 2021

2048 Convertible Senior Notes

Accounting for Convertible Senior Notes — Upon issuance in 2018, the Convertible Senior Notes were separated into liability and equity components for accounting purposes. The carrying amount of the liability component was initially calculated by measuring the fair value of similar liabilities that do not have an associated convertible feature. The carrying amount of the equity component representing the conversion option was determined by deducting the fair value of the liability component from the par value of the Convertible Senior Notes. This difference represented the debt discount that was amortized to interest expense over seven years, which was determined to be the expected life of the Convertible Senior Notes, using the effective interest rate method. The equity component was recorded in additional paid-in capital and was not remeasured as it continued to meet the conditions for equity classification.

Following the adoption of ASU 2020-06 as of January 1, 2022, the Company no longer records the conversion feature of its convertible senior notes in equity. Instead, the Company combined the previously separated equity component with the liability component, which together is now classified as debt, thereby eliminating the subsequent amortization of the debt discount as interest expense. As a result of the provisions of the amended guidance, the Company recorded a $100 million decrease to additional paid-in capital, a $57 million decrease to debt discount, a $57 million increase to retained earnings, and a $14 million decrease to long-term deferred tax liabilities.

Modification to Convertible Senior Notes — On February 22, 2022, the Company irrevocably elected to eliminate the right to settle conversions only in shares of the Company's common stock, such that any conversion after such date, the Company will pay cash per $1,000 principal amount and will settle in cash or a combination of cash and the Company's common stock for the remainder, if any, of the Company’s conversion obligation in excess of the aggregate principal amount.

Convertible Senior Notes Features — As of December 31, 2023, the Convertible Senior Notes were convertible, under certain circumstances, into cash or a combination of cash and the Company’s common stock at a price of $41.83 per common share, which is equivalent to a conversion rate of approximately 23.9079 shares of common stock per $1,000 principal amount of Convertible Senior Notes. As of December 31, 2022, the Convertible Senior Notes were convertible at a price of $43.46 per common share, which is equivalent to a conversion rate of approximately 23.0116 shares of common stock per $1,000 principal amount of Convertible Senior Notes. The net carrying amounts of the Convertible Senior Notes as of December 31, 2023 and December 31, 2022 were $572 million and $570 million, respectively. The Convertible Senior Notes mature on June 1, 2048, unless earlier repurchased, redeemed or converted in accordance with their terms. The Convertible Senior Notes are convertible at the option of the holders under certain circumstances. Prior to the close of business on the business day immediately preceding December 1, 2024, the Convertible Senior Notes will be convertible only upon the occurrence of certain events and during certain periods, including, among others, during any calendar quarter (and only during such calendar quarter) if the last reported sales price per share of the Company's common stock exceeds 130% of the conversion price for each of at least 20 trading days, whether or not consecutive, during the 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter. Thereafter during specified periods as follows:

•from December 1, 2024 until the close of business on the second scheduled trading day immediately before June 1, 2025; and

•from December 1, 2047 until the close of business on the second scheduled trading day immediately before the maturity date

All conversions with a conversion date that occurs within the specific periods above will be settled after such period pursuant to the terms of the indenture. The following table details the interest expense recorded in connection with the Convertible Senior Notes, due 2048:

	For the years ended December 31,
($ In millions)	2023			2022			2021
Contractual interest expense	$	16		$	16		$	16
Amortization of discount and deferred finance costs(a)	2			1			15
Total	$	18		$	17		$	31
Effective Interest Rate	3.18		%	3.01		%	5.34		%

(a)Upon adoption of ASU 2020-06 on January 1, 2022, which resulted in the removal of the debt discount, no further debt discount amortization is being recorded

Senior Notes Early Redemption

As of December 31, 2023, NRG had the following outstanding issuances of senior notes with an early redemption feature, or Senior Notes:

i.6.625% senior notes, issued August 2, 2016 and due January 15, 2027, or the 2027 Senior Notes;

ii.5.750% senior notes, issued December 7, 2017 and due January 15, 2028, or the 2028 Senior Notes;

iii.5.250% senior notes, issued May 24, 2019 and due June 15, 2029, or the 2029 Senior Notes;

iv.3.375% senior notes, issued December 2, 2020 and due February 15, 2029, or the 3.375% 2029 Senior Notes;

v.3.625% senior notes, issued December 2, 2020 and due February 15, 2031, or the 2031 Senior Notes; and

vi.3.875% senior notes, issued August 23, 2021 and due February 15, 2032, or the 2032 Senior Notes.

The indentures and the forms of notes provide, among other things, that the Senior Notes will be senior unsecured obligations of the Company. The indentures also provide for customary events of default, which include, among others: nonpayment of principal or interest; breach of other agreements in the indentures; defaults in failure to pay certain other indebtedness; the rendering of judgments to pay certain amounts of money against the Company and its subsidiaries; the failure of certain guarantees to be enforceable; and certain events of bankruptcy or insolvency. Generally, if an event of default occurs, the trustee or the holders of at least 25% or 30% (depending on the series of Senior Notes) in principal amount of the then outstanding series of Senior Notes may declare all of the Senior Notes of such series to be due and payable immediately. The terms of the indentures, among other things, limit the Company's ability and certain of its subsidiaries' ability to return capital to stockholders, grant liens on assets to lenders and incur additional debt. Interest is payable semi-annually on the Senior Notes until their maturity dates.

2027 Senior Notes

The Company may redeem some or all of the 2027 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
July 15, 2023 to July 14, 2024	101.104	%
July 15, 2024 and thereafter	100.000	%

2028 Senior Notes

The Company may redeem some or all of the 2028 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
January 15, 2024 to January 14, 2025	101.917	%
January 15, 2025 to January 14, 2026	100.958	%
January 15, 2026 and thereafter	100.000	%

5.250% 2029 Senior Notes

At any time prior to June 15, 2024, the Company may redeem all or a part of the 5.250% 2029 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the notes; or (ii) the excess of the principal amount of the note over the following: the present value of 102.625% of the note, plus interest payments due on the note through June 15, 2024 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the principal amount of the note. In addition, on or after June 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
June 15, 2024 to June 14, 2025	102.625	%
June 15, 2025 to June 14, 2026	101.750	%
June 15, 2026 to June 14, 2027	100.875	%
June 15, 2027 and thereafter	100.000	%

3.375% 2029 Senior Notes

On or after February 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 to February 14, 2026	100.844	%
February 15, 2026 and thereafter	100.000	%

2031 Senior Notes

At any time prior to February 15, 2026, the Company may redeem all or a part of the 2031 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the note; or (ii) the excess of the present value of 101.813% of the note, plus interest payments due on the note through February 15, 2026 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the principal amount of the note. In addition, on or after February 15, 2026, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2026 to February 14, 2027	101.813	%
February 15, 2027 to February 14, 2028	101.208	%
February 15, 2028 to February 14, 2029	100.604	%
February 15, 2029 and thereafter	100.000	%

2032 Senior Notes

At any time prior to August 15, 2024, the Company may redeem up to 40% of the aggregate principal amount of the 2032 Senior Notes, at a redemption price equal to 103.875% of the principal amount of the notes redeemed, plus accrued and unpaid interest, with an amount equal to the net cash proceeds of certain equity offerings, provided that at least 50% of the aggregate principal amount remains outstanding immediately after the occurrence of such redemption. At any time prior to February 15, 2027, the Company may redeem all or a part of the 2032 Senior Notes, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the notes; or (ii) the excess of (A) the present value of (1) the redemption price of the note at February 15, 2027 (such redemption price being set forth in the table appearing below in the column “Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)” unless the Sustainability Performance Target has been satisfied in respect of the year ended December 31, 2025 and the Company has provided confirmation thereof to the trustee together with a related confirmation by the External Verifier by the date that is at least 15 days prior to August 15, 2026 in which case the redemption price shall be as set forth in the column “Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)”) plus (2) interest payments due on the note through February 15, 2027 (excluding accrued but unpaid interest to the redemption date) computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50%, over (B) the principal amount of the note. In addition, on or after February 15, 2027, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table during the twelve-month period beginning on February 15 of the years indicated below, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Year	Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)		Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)
2027	101.938	%	102.188	%
2028	101.292	%	101.458	%
2029	100.646	%	100.729	%
2030 and thereafter	100.000	%	100.000	%

Receivables Facility

In 2020, NRG Receivables LLC, a bankruptcy remote, special purpose, indirect wholly owned subsidiary, ("NRG Receivables") entered into the Receivables Facility, subject to adjustments on a seasonal basis, with issuers of asset-backed commercial paper and commercial banks (the "Lenders"). The assets of NRG Receivables are first available to satisfy the claims of the Lenders before making payments on the subordinated note and equity issued by NRG Receivables. The assets of NRG Receivables are not available to the Company and its subsidiaries or creditors unless and until distributed by NRG Receivables. Under the Receivables Facility, certain indirect subsidiaries of the Company sell their accounts receivables to NRG Receivables, subject to certain terms and conditions. In turn, NRG Receivables grants a security interest in the purchased receivables to the Lenders as collateral for cash borrowings and issuances of letters of credit. Pursuant to the Performance Guaranty, the Company has guaranteed, for the benefit of NRG Receivables and the Lenders, the payment and performance by each indirect subsidiary of its respective obligations under the Receivables Facility. The accounts receivables remain on the

Company's consolidated balance sheet and any amounts funded by the Lenders to NRG Receivables will be reflected as short-term borrowings. Cash flows from the Receivables Facility are reflected as financing activities in the Company's consolidated statements of cash flows. The Company continues to service the accounts receivables sold in exchange for a servicing fee.

On June 22, 2023, NRG Receivables amended its existing Receivables Facility to, among other things, (i) extend the scheduled termination date to June 21, 2024, (ii) increase the aggregate commitments from $1.0 billion to $1.4 billion (adjusted seasonally) and (iii) add a new originator. On October 6, 2023, the Receivables Facility was further amended to replace the benchmark interest rate of the Receivable Facility's subordinated note from LIBOR to SOFR. The weighted average interest rate related to usage under the Receivables Facility as of December 31, 2023 was 0.841%. As of December 31, 2023, there were no outstanding borrowings and there were $1.0 billion in letters of credit issued under the Receivables Facility.

Repurchase Facility

In 2020, the Company entered into the Repurchase Facility related to the Receivables Facility. Under the Repurchase Facility, the Company can currently borrow up to $150 million, collateralized by a subordinated note issued by NRG Receivables to NRG Retail LLC in favor of the originating entities representing a portion of the balance of receivables sold to NRG Receivables under the Receivables Facility.

In addition, in connection with the amendments to the Receivables Facility, on June 22, 2023, the Company and the originators thereunder renewed the existing uncommitted Repurchase Facility. Such renewal, among other things, extended the maturity date to June 21, 2024 and joined an additional originator to the Repurchase Facility. On October 6, 2023, the Repurchase Facility was further amended to reflect the concurrent amendment to the Receivables Facility's subordinated note. The Repurchase Facility has no commitment fee and borrowings will be drawn at SOFR + 1.55%. As of December 31, 2023, there were no outstanding borrowings under the Repurchase Facility.

Bilateral Letter of Credit Facilities

On May 19, 2023, May 30, 2023 and October 17, 2023 the Company increased the size of its bilateral letter of credit facilities by $25 million, $100 million and $50 million, respectively, to provide additional liquidity and to allow for the issuance of up to $850 million of letters of credit. These facilities are uncommitted. As of December 31, 2023, $671 million was issued under these facilities.

Tax Exempt Bonds

	As of December 31,
(In millions, except rates)	2023		2022		Interest Rate %
NRG Indian River Power 2020, tax exempt bonds, due 2040	$	57	$	57	1.250
NRG Indian River Power 2020, tax exempt bonds, due 2045	190		190		1.250
NRG Dunkirk 2020, tax exempt bonds, due 2042	59		59		4.250
City of Texas City, tax exempt bonds, due 2045	33		33		4.125
Fort Bend County, tax exempt bonds, due 2038	54		54		4.750
Fort Bend County, tax exempt bonds, due 2042	73		73		4.750
Total	$	466	$	466

Dunkirk Bonds

On April 3, 2023, NRG remarketed $59 million in aggregate principal amount of 4.25% tax-exempt refinancing bonds of the Chautauqua County Capital Resource Corporation (the "Dunkirk Bonds"). The Dunkirk Bonds are guaranteed on a first-priority basis by each of NRG's current and future subsidiaries that guarantee indebtedness under the Revolving Credit Facility. The Dunkirk Bonds are secured by a first priority security interest in the same collateral that is pledged for the benefit of the lenders under the Revolving Credit Facility, which consists of a substantial portion of the property and assets owned by NRG and the guarantors. The collateral securing the Dunkirk Bonds will, at the request of NRG, be released if NRG satisfies certain conditions, including receipt of an investment grade rating on its senior, unsecured debt securities from two out of the three rating agencies, subject to reversion if those rating agencies withdraw their investment grade rating of the Dunkirk Bonds or any of NRG's senior, unsecured debt securities or downgrade such ratings below investment grade. The Dunkirk Bonds are subject to mandatory tender and purchase on April 3, 2028 and have a final maturity date of April 1, 2042.

Pre-Capitalized Trust Securities Facility

On August 29, 2023, the Company entered into a Facility Agreement (as defined below) with Alexander Funding Trust II, a newly-formed Delaware statutory trust (the “Trust”), in connection with the sale by the Trust of $500 million pre-capitalized trust securities redeemable July 31, 2028 (the “P-Caps”). The Trust invested the proceeds from the sale of the P-Caps in a portfolio of principal and interest strips of U.S. Treasury securities (the “Eligible Treasury Assets”). The P-Caps replaced the Company’s existing pre-capitalized trust securities redeemable 2023 issued by Alexander Funding Trust, which matured on November 15, 2023.

In connection with the sale of the P-Caps, the Company and the guarantors named therein entered into a facility agreement, dated August 29, 2023 (the “Facility Agreement”), with the Trust and Deutsche Bank Trust Company Americas, as notes trustee (the “Notes Trustee”). Under the Facility Agreement, the Company has the right, from time to time, to issue to the Trust, and to require the Trust to purchase from the Company, on one or more occasions (the “Issuance Right”), up to $500 million aggregate principal amount of the Company’s 7.467% Senior Secured First Lien Notes due 2028 (the “P-Caps Secured Notes”) in exchange for all or a portion of the Eligible Treasury Assets corresponding to the portion of the Issuance Right under the Facility Agreement being exercised at such time. The Company pays to the Trust a facility fee equal to 3.13427% applied to the unexercised portion of the Issuance Right on a semi-annual basis.

The P-Caps are to be redeemed by the Trust on July 31, 2028 or earlier upon an early redemption of the P-Caps Secured Notes. Following any distribution of P-Caps Secured Notes to the holders of the P-Caps, the Company may similarly redeem such P-Caps Secured Notes, in whole or in part, at the redemption price described in the P-Caps Indenture (as defined below), plus accrued but unpaid interest to, but excluding, the date of redemption. Any P-Caps Secured Notes outstanding and held by the Trust as a result of the exercise of the Issuance Right that remain outstanding will also mature on July 31, 2028.

The Issuance Right will be exercised automatically in full if (i) the Company fails to pay the facility fee when due or any amount due and owing under the trust expense reimbursement agreement or fails to purchase and pay for any Eligible Treasury Assets that are due and not paid on their payment date and such failure is not cured within 30 days or (ii) upon certain bankruptcy events of the Company. The Company will be required to mandatorily exercise the Issuance Right if certain mandatory exercise events occur upon the terms and conditions set forth in the Facility Agreement.

The P-Caps Secured Notes that may be sold to the Trust from time to time will be governed by the base indenture, dated August 29, 2023 (the “Base Indenture”), between the Company and the Notes Trustee, as supplemented by the supplemental indenture, dated August 29, 2023 (the “Supplemental Indenture” and, together with the Base Indenture, the “P-Caps Indenture”), among the Company, the guarantors named therein and the Notes Trustee.

The P-Caps Secured Notes will, if sold to the Trust, be guaranteed on a first-priority basis by each of the Company’s subsidiaries that guarantee indebtedness under the Revolving Credit Facility. The P-Caps Secured Notes will, if sold to the Trust, be secured by a first priority security interest in the same collateral that is pledged for the benefit of the lenders under the Revolving Credit Facility, which consists of a substantial portion of the property and assets owned by the Company and the guarantors. The collateral securing the P-Caps Secured Notes will be released at the Company’s request if the senior unsecured long-term debt securities of the Company are rated investment grade by any two of the three rating agencies, subject to reversion if such rating agencies downgrade such rating below investment grade or withdraw such investment grade rating.

In connection with the issuance of the P-Caps, on August 29, 2023, the Company entered into a letter of credit facility agreement (the “LC Agreement”) with Deutsche Bank Trust Company Americas, as collateral agent (the “Collateral Agent”) and administrative agent, and certain financial institutions (the “LC Issuers”) for the issuance of letters of credit in an aggregate amount not to exceed $485 million. The LC Agreement replaced the Company’s existing letter of credit facility agreement, effective August 29, 2023. In addition, on August 29, 2023, the Trust entered into a pledge and control agreement (the “Pledge Agreement”), among the Company, the Trust and the Collateral Agent, under which the Company and the Trust agreed to grant a security interest over the Eligible Treasury Assets in favor of the Collateral Agent for the benefit of the LC Issuers. Pursuant to the LC Agreement and the Pledge Agreement, the Collateral Agent is entitled to withdraw Eligible Treasury Assets in the amount of any drawn letters of credit issued pursuant to the LC Agreement from the Company's and the Trust’s pledged accounts, following notice to the Company, in the event the Company has failed to reimburse such drawn amounts and the LC Issuers have the right to instruct the Collateral Agent to enforce the pledge over the Eligible Treasury Assets upon the occurrence of any event of default under the LC Agreement.

Non-recourse Debt

The following are descriptions of certain indebtedness of NRG's subsidiaries. All of NRG's non-recourse debt is secured by the assets in the subsidiaries as further described below.

Acquired Vivint Smart Home Debt

On March 10, 2023, in connection with the Vivint Smart Home acquisition, Vivint Smart Home's indirect wholly owned subsidiary, APX Group, Inc. ("APX"), retained its 6.750% senior secured notes due 2027, 5.750% senior notes due 2029, senior secured term loan credit agreement and senior secured revolving credit facility.

Vivint Smart Home 2027 Senior Secured Notes

Vivint Smart Home has outstanding $600 million aggregate principal amount of 6.750% senior secured notes due 2027 (the "Vivint Smart Home 2027 Senior Secured Notes"). The Vivint Smart Home 2027 Senior Secured Notes are senior secured obligations of APX and are guaranteed by APX Group Holdings, Inc., each of APX's existing and future wholly owned U.S. restricted subsidiaries (subject to customary exclusions and qualifications) and Vivint Smart Home. Interest on the Vivint Smart Home 2027 Senior Secured Notes is paid semi-annually in arrears on February 15 and August 15 until the maturity date of February 15, 2027.

Vivint Smart Home 2029 Senior Notes

Vivint Smart Home has outstanding $800 million aggregate principal amount of 5.750% senior notes due 2029 (the "Vivint Smart Home 2029 Senior Notes"). The Vivint Smart Home 2029 Senior Notes are senior unsecured obligations of APX and are guaranteed by APX Group Holdings, Inc., each of APX's existing and future wholly owned U.S. restricted subsidiaries (subject to customary exclusions and qualifications) and Vivint Smart Home. Interest on the Vivint Smart Home 2029 Senior Notes is paid semi-annually in arrears on January 15 and July 15 until the maturity date of July 15, 2029.

Vivint Smart Home Senior Secured Credit Facilities

The Vivint Smart Home senior secured credit agreement (the “Vivint Smart Home Credit Agreement”) provides for (i) a term loan facility in an initial aggregate principal amount of $1.4 billion (the “Vivint Smart Home Term Loan Facility”, and the loans thereunder, the “Vivint Smart Home Term Loans”) and (ii) a revolving credit facility in an initial aggregate principal amount of $370 million (the “Vivint Smart Home Revolving Credit Facility,” and the loans thereunder, the “Vivint Smart Home Revolving Loans”).

All of APX’s obligations under the Vivint Smart Home Credit Agreement are guaranteed by APX Group Holdings, Inc. and each of APX’s existing and future wholly-owned U.S. restricted subsidiaries (subject to customary exclusions and qualifications). The obligations under the Vivint Smart Home Credit Agreement are secured by a first priority (subject to certain customary permitted liens) perfected security interest in (i) substantially all of the present and future tangible and intangible assets of APX, and the guarantors, including without limitation equipment, subscriber contracts and communication paths, intellectual property, general intangibles, investment property, material intercompany notes and proceeds of the foregoing, subject to permitted liens and other customary exceptions, (ii) substantially all personal property of APX and the guarantors consisting of accounts receivable arising from the sale of inventory and other goods and services (including related contracts and contract rights, inventory, cash, deposit accounts, other bank accounts and securities accounts), inventory and intangible assets to the extent attached to the foregoing books and records of APX and the guarantors, and the proceeds thereof, subject to permitted liens and other customary exceptions, in each case held by APX and the guarantors and (iii) a pledge of all of the capital stock of APX, each of its subsidiary guarantors and each restricted subsidiary of APX and its subsidiary guarantors (subject to customary exclusions and qualifications), in each case other than certain excluded assets and subject to the limitations and exclusions provided in the applicable collateral documents.

The Vivint Smart Home Credit Agreement contains customary covenants, which, among other things, require APX to maintain a maximum first lien net leverage ratio when amounts outstanding under the Vivint Smart Home Revolving Facility exceed a certain threshold and restrict, subject to certain exceptions, APX and its restricted subsidiaries’ ability to:

•incur or guarantee additional debt or issue disqualified stock or preferred stock;

•pay dividends and make other distributions on, or redeem or repurchase, capital stock;

•make certain investments;

•incur certain liens;

•enter into transactions with affiliates;

•merge or consolidate;

•materially change the nature of their business;

•enter into agreements that restrict the ability of restricted subsidiaries to make dividends or other payments to APX or grant liens on their assets;

•designate restricted subsidiaries as unrestricted subsidiaries;

•amend, prepay, redeem or purchase certain material contractually subordinated debt; and

•transfer or sell certain assets.

On June 9, 2023, Vivint Smart Home entered into an amendment to the Vivint Smart Home Credit Agreement which transitioned the benchmark rate applicable to the Vivint Smart Home Term Loans and the Vivint Smart Home Revolving Loans from LIBOR to SOFR. As of December 31, 2023, the aggregate outstanding principal amount of the Vivint Term Loans was $1.3 billion. As of December 31, 2023, Vivint Smart Home had no outstanding borrowings under the Vivint Smart Home Revolving Credit Facility.

Vivint Smart Home Notes Early Redemption

2027 Senior Secured Notes

APX may redeem some or all of the 2027 Senior Secured Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 and thereafter	100.000	%

2029 Senior Notes

At any time prior to July 15, 2024 and from time to time, APX may redeem the notes in whole or in part, at a redemption price equal to 100% of the principal amount of the notes redeemed, plus accrued and unpaid interest to the redemption date, plus a premium. The premium is the greater of: (i) 1% of the principal amount of the note; and (ii) the excess , if any, of (a) the present value at such redemption date of (i) the redemption price of such note at July 15, 2024, plus (ii) interest payments due on the note through July 15, 2024 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the Treasury Rate as of such redemption date plus 0.50% over the then outstanding principal amount of such note. In addition, on or after July 15, 2024, APX may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
July 15, 2024 to July 14, 2025	102.875	%
July 15, 2025 to July 14, 2026	101.438	%
July 15, 2026 and thereafter	100.100	%

Annual Payments Based On the Maturities of NRG's Debt

As of December 31, 2023, annual payments based on the maturities of NRG's debt and finance leases are expected to be as follows:

	(In millions)
2024	$	620
2025	769
2026	16
2027	1,890
2028	2,145
Thereafter	5,519
Total	$	10,959

Senior Note Redemptions

(In millions, except percentages)	Principal Repurchased		Cash Paid(a)		Average Early Redemption Percentage
7.250% Senior Notes, due 2026	$	1,000	$	1,056	103.625	%
6.625% Senior Notes, due 2027	855		893		103.313	%
Total	$	1,855	$	1,949

(a)Includes accrued interest of $29 million for redemptions for the year ended December 31, 2021

The Company may redeem some or all of the 2027 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
July 15, 2023 to July 14, 2024	101.104	%
July 15, 2024 and thereafter	100.000	%

The Company may redeem some or all of the 2028 Senior Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
January 15, 2024 to January 14, 2025	101.917	%
January 15, 2025 to January 14, 2026	100.958	%
January 15, 2026 and thereafter	100.000	%

In addition, on or after June 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
June 15, 2024 to June 14, 2025	102.625	%
June 15, 2025 to June 14, 2026	101.750	%
June 15, 2026 to June 14, 2027	100.875	%
June 15, 2027 and thereafter	100.000	%

On or after February 15, 2024, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 to February 14, 2026	100.844	%
February 15, 2026 and thereafter	100.000	%

In addition, on or after February 15, 2026, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2026 to February 14, 2027	101.813	%
February 15, 2027 to February 14, 2028	101.208	%
February 15, 2028 to February 14, 2029	100.604	%
February 15, 2029 and thereafter	100.000	%

In addition, on or after February 15, 2027, the Company may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table during the twelve-month period beginning on February 15 of the years indicated below, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Year	Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)		Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)
2027	101.938	%	102.188	%
2028	101.292	%	101.458	%
2029	100.646	%	100.729	%
2030 and thereafter	100.000	%	100.000	%

APX may redeem some or all of the 2027 Senior Secured Notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
February 15, 2024 to February 14, 2025	101.688	%
February 15, 2025 and thereafter	100.000	%

In addition, on or after July 15, 2024, APX may redeem some or all of the notes at redemption prices expressed as percentages of principal amount as set forth in the following table, plus accrued and unpaid interest on the notes redeemed to the first applicable redemption date:

Redemption Period	Redemption Percentage
July 15, 2024 to July 14, 2025	102.875	%
July 15, 2025 to July 14, 2026	101.438	%
July 15, 2026 and thereafter	100.100	%

Schedule of Interest Expense, Convertible Senior Notes

The following table details the interest expense recorded in connection with the Convertible Senior Notes, due 2048:

	For the years ended December 31,
($ In millions)	2023			2022			2021
Contractual interest expense	$	16		$	16		$	16
Amortization of discount and deferred finance costs(a)	2			1			15
Total	$	18		$	17		$	31
Effective Interest Rate	3.18		%	3.01		%	5.34		%

(a)Upon adoption of ASU 2020-06 on January 1, 2022, which resulted in the removal of the debt discount, no further debt discount amortization is being recorded

Schedule of Tax Exempt Bonds

Tax Exempt Bonds

	As of December 31,
(In millions, except rates)	2023		2022		Interest Rate %
NRG Indian River Power 2020, tax exempt bonds, due 2040	$	57	$	57	1.250
NRG Indian River Power 2020, tax exempt bonds, due 2045	190		190		1.250
NRG Dunkirk 2020, tax exempt bonds, due 2042	59		59		4.250
City of Texas City, tax exempt bonds, due 2045	33		33		4.125
Fort Bend County, tax exempt bonds, due 2038	54		54		4.750
Fort Bend County, tax exempt bonds, due 2042	73		73		4.750
Total	$	466	$	466

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Asset Retirement Obligations (Tables)

12 Months Ended

Dec. 31, 2023

Asset Retirement Obligation Disclosure [Abstract]

Schedule of ARO Obligations and Related Additions, Reductions and Accretion

The following table represents the balance of ARO obligations as of December 31, 2023 and 2022, along with the activity related to the Company's ARO obligations for the year ended December 31, 2023:

(In millions)	Nuclear Decommission		Other(a)		Total
Balance as of December 31, 2022	$	340	$	418	$	758
Revisions in estimates for current obligations	(13)		3		(10)
Additions	—		13		13
Spending for current obligations	—		(42)		(42)
Accretion	16		23		39
Dispositions	(343)		(8)		(351)
Balance as of December 31, 2023	$	—	$	407	$	407

(a)Total accretion expense related to asset retirement obligations included in the consolidated statement of cash flows includes accretion and revisions in estimates for asset retirement liabilities on non-operating plants

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Benefit Plans and Other Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2023

Retirement Benefits [Abstract]

Schedule of Net Benefit Cost (Credit) Related to Pension and Other Postretirement Benefit Plans Components

The annual net periodic benefit cost/(credit) related to NRG's pension and other postretirement benefit plans include the following components:

	Year Ended December 31,
	Pension Benefits
(In millions)	2023		2022		2021
Service cost benefits earned	$	5	$	7	$	9
Interest cost on benefit obligation	50		41		27
Expected return on plan assets	(39)		(47)		(66)
Amortization of unrecognized net loss	6		3		1
Curtailment and special termination benefits (income)/expense	(1)		14		2
Net periodic benefit cost/(credit)	$	21	$	18	$	(27)

	Year Ended December 31,
	Other Postretirement Benefits
(In millions)	2023		2022		2021
Interest cost on benefit obligation	$	4	$	2	$	2
Amortization of unrecognized prior service cost	(8)		(8)		(10)
Amortization of unrecognized net loss	1		2		1
Curtailment expense	—		—		1
Net periodic benefit credit	$	(3)	$	(4)	$	(6)

Schedule of Comparison of Pension Benefit obligation, Other Postretirement Benefit Obligations and Related Plan Assets on a Combined Basis

A comparison of the pension benefit obligation, other postretirement benefit obligations and related plan assets for NRG's plans on a combined basis is as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Benefit obligation at January 1	$	1,036	$	1,452	$	84	$	105
Service cost	5		7		—		—
Interest cost	50		41		4		2
Actuarial loss/(gain)	22		(289)		(5)		(11)
Employee and retiree contributions	—		—		4		3
Curtailment and special termination benefit loss	(2)		—		(1)		—
Benefit payments	(89)		(171)		(11)		(15)
Foreign exchange translation	1		(4)		—		—
Benefit obligation at December 31	1,023		1,036		75		84
Fair value of plan assets at January 1	844		1,336		—		—
Actual return on plan assets	93		(317)		—		—
Employee and retiree contributions	—		—		4		3
Employer contributions	2		—		7		12
Benefit payments	(89)		(171)		(11)		(15)
Foreign exchange translation	1		(4)		—		—
Fair value of plan assets at December 31	851		844		—		—
Funded status at December 31 — excess of obligation over assets	$	(172)	$	(192)	$	(75)	$	(84)

Schedule of Amounts Recognized in Balance Sheet

Amounts recognized in NRG's balance sheets were as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Other current liabilities	$	—	$	—	$	5	$	7
Other non-current liabilities	172		192		70		77

Schedule of Amounts Recognized in OCI Not Yet Recognized as Components of Net Periodic Benefit Costs

Amounts recognized in NRG's accumulated OCI that have not yet been recognized as components of net periodic benefit cost were as follows:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Net loss/(gain)	$	73	$	110	$	(14)	$	(7)
Prior service cost/(credit)	—		1		(4)		(12)
Total accumulated OCI	$	73	$	111	$	(18)	$	(19)

Schedule of Changes in Plan Assets and Benefit Obligations Recognized in Other Comprehensive Income

Other changes in plan assets and benefit obligations recognized in OCI were as follows:

	Year Ended December 31,
	Pension Benefits				Other Postretirement Benefits
(In millions)	2023		2022		2023		2022
Net actuarial (gain)/loss	$	(31)	$	74	$	(5)	$	(11)
Amortization of net actuarial loss	(6)		(3)		(1)		(2)
Amortization of prior service cost	—		—		8		8
Effect of settlement/curtailment	(1)		(14)		(1)		—
Total recognized in OCI	$	(38)	$	57	$	1	$	(5)
Net periodic benefit cost/(credit)	21		18		(3)		(4)
Net recognized in net periodic pension (credit)/cost and OCI	$	(17)	$	75	$	(2)	$	(9)

Schedule of Benefit Obligations Significant Components

The following table presents the balances of significant components of NRG's pension plan:

	As of December 31,
	Pension Benefits
(In millions)	2023		2022
Projected benefit obligation	$	1,023	$	1,036
Accumulated benefit obligation	1,015		1,022
Fair value of plan assets	851		844

Schedule of Fair Value of Pension Plan Assets by Asset Category and Level within the Fair Value Hierarchy

NRG's market-related value of its plan assets is the fair value of the assets. The fair values of the Company's pension plan assets by asset category and their level within the fair value hierarchy are as follows:

	Fair Value Measurements as of December 31, 2023
(In millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Total
Common/collective trust investment — U.S. equity	$	—	$	156	$	156
Common/collective trust investment — non-U.S. equity	—		58		58
Common/collective trust investment — non-core assets	—		81		81
Common/collective trust investment — fixed income	—		188		188
Short-term investment fund	19		—		19
Subtotal fair value	$	19	$	483	$	502
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					32
Common/collective trust investment — fixed income					243
Common/collective trust investment — non-core assets					47
Partnerships/joint ventures					27
Total fair value					$	851

	Fair Value Measurements as of December 31, 2022
(In millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Observable Inputs (Level 2)		Total
Common/collective trust investment — U.S. equity	$	—	$	155	$	155
Common/collective trust investment — non-U.S. equity	—		65		65
Common/collective trust investment — non-core assets	—		90		90
Common/collective trust investment — fixed income	—		181		181
Short-term investment fund	22		—		22
Subtotal fair value	$	22	$	491	$	513
Measured at net asset value practical expedient:
Common/collective trust investment — non-U.S. equity					33
Common/collective trust investment — fixed income					220
Common/collective trust investment — non-core assets					55
Partnerships/joint ventures					23
Total fair value					$	844

Schedule of Assumptions Used to Calculate Benefit Expense

The following table presents the significant assumptions used to calculate NRG's benefit obligations:

	As of December 31,
	Pension Benefits				Other Postretirement Benefits
Weighted-Average Assumptions	2023		2022		2023		2022
Discount rate	4.97	%	5.18	%	4.96	%	5.19	%
Interest crediting rate	5.67	%	5.21	%	4.66	%	4.00	%
Rate of compensation increase	3.06	%	3.06	%	—		—
Health care trend rate	—		—		7.7% grading to 4.5% in 2033		7% grading to 4.4% in 2031

The following table presents the significant assumptions used to calculate NRG's benefit expense:

	As of December 31,
	Pension Benefits						Other Postretirement Benefits
Weighted-Average Assumptions	2023		2022		2021		2023		2022		2021
Discount rate	5.18	%	2.89%/4.71%/5.41%		2.55	%	5.19	%	2.82	%	2.81	%
Interest crediting rate	5.21	%	3.07	%	3.13	%	4.00	%	1.94	%	1.62	%
Expected return on plan assets	5.55	%	4.99	%	5.62	%	—		—		—
Rate of compensation increase	3.06	%	3.06	%	3.06	%	—		—		—
Health care trend rate	—		—		—		7.2% grading to 4.5% in 2028		6.9% grading to 4.4% in 2028		7.0% grading to 4.4% in 2028

Schedule of Target Allocation of Pension Plan Assets

The target allocations of NRG's pension plan assets were as follows for the year ended December 31, 2023:

U.S. equity	19	%
Non-U.S. equity	12	%
Non-core assets	17	%
Fixed Income	52	%

Schedule of Performance Benchmarks

Performance benchmarks are composed of the following indices:

Asset Class	Index
U.S. equities	Dow Jones U.S. Total Stock Market Index
Non-U.S. equities	MSCI All Country World Index
Non-core assets(a)	Various (per underlying asset class)
Fixed income securities	Barclays Short, Intermediate and Long Credits/Barclays Strips 20+ Index and FTSE Canada Universe Bond Index

(a)Non-Core Assets are defined as diversifying asset classes approved by the Investment Committee that are intended to enhance returns and/or reduce volatility of the U.S. and non-U.S. equities. Asset classes considered Non-Core include, but may not be limited to: Emerging Market Equity, Emerging Market Debt, Non-US Developed Market Small Cap, High Yield Fixed Income, Real Estate, Bank Loans, Global Infrastructure and other Alternatives

Schedule of Expected Benefit Payments

NRG's expected future benefit payments for each of the next five years, and in the aggregate for the five years thereafter, are as follows:

	Pension		Other Postretirement Benefit
(In millions)	Benefit Payments		Benefit Payments		Medicare Prescription Drug Reimbursements
2024	$	82	$	5	$	—
2025	81		5		—
2026	79		5		—
2027	78		5		—
2028	76		5		—
2029-2033	360		27		2

Schedule of Benefit Costs and Other Changes Recognized in the Financial Statements Related to its Interest in STP

The Company recognized the following in its statement of financial position, statement of operations and accumulated OCI related to its former 44% interest in STP:

	As of December 31,
	Pension Benefits		Other Postretirement Benefits
(In millions)	2022		2022
Funded status — STPNOC benefit plans	$	(7)	$	(13)
Net periodic benefit cost/(credit)	2		(4)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(27)		1

Defined Contribution Plan Contributions

The Company's costs related to these plans were as follows:

	Year Ended December 31,
(In millions)	2023		2022		2021
Cost recognized for defined contribution plans	$	61	$	37	$	35

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Capital Structure (Tables)

12 Months Ended

Dec. 31, 2023

Equity [Abstract]

Changes in NRG's common shares issued and outstanding

The following table reflects the changes in NRG's preferred and common shares issued and outstanding for each period presented:

	Preferred Shares	Common Shares
	Issued and Outstanding	Issued	Treasury	Outstanding
Balance as of December 31, 2020	—	423,057,848	(178,825,915)	244,231,933
Shares issued under ESPP	—	—	117,392	117,392
Shares issued under LTIPs	—	489,326	—	489,326
Share repurchases	—	—	(1,084,752)	(1,084,752)
Balance as of December 31, 2021	—	423,547,174	(179,793,275)	243,753,899
Shares issued under ESPP	—	—	142,825	142,825
Shares issued under LTIPs	—	349,827	—	349,827
Share repurchases	—	—	(14,685,521)	(14,685,521)
Balance as of December 31, 2022	—	423,897,001	(194,335,971)	229,561,030
Issuance of Series A Preferred Stock	650,000	—	—	—
Shares issued under ESPP	—	—	191,249	191,249
Shares issued under LTIPs	—	1,109,611	—	1,109,611
Share repurchases	—	—	(22,730,940)	(22,730,940)
Retirement of treasury stock	—	(157,676,142)	157,676,142	—
Balance as of December 31, 2023	650,000	267,330,470	(59,199,520)	208,130,950
Shares issued under LTIPs	—	660,267	—	660,267
Share repurchases	—	—	(770,205)	(770,205)
Retirement of treasury stock	—	(770,205)	770,205	—
Balance as of February 1, 2024	650,000	267,220,532	(59,199,520)	208,021,012

Summary of shares repurchased

The following table summarizes the share repurchases made from 2021 through February 1, 2024:

	Total number of shares purchased	Average price paid per share		Amounts paid for shares purchased (in millions)
2021 Repurchases:
Open market repurchases(a)	1,084,752	$	40.85	$	44
2022 Repurchases:
Open market repurchases	14,685,521	40.48		595
2023 Repurchases:
Open market repurchases	5,054,798			200
Repurchases made under the accelerated share repurchase agreements(b)	17,676,142			950
Total Share Repurchases during 2023	22,730,940	(e)		$	1,150	(c)
Repurchases made subsequent to December 31, 2023 under the accelerated share repurchase agreements(d)	770,205			—
Total Share Repurchases January 1, 2023 through February 1, 2024	23,501,145	(e)		$	1,150

(a)Includes $5 million accrued as of December 31, 2021

(b)Initial and interim shares delivered under the November 6, 2023 accelerated share repurchase agreements

(c)Excludes $10 million accrued for excise tax owed as of December 31, 2023

(d)Additional shares delivered under the November 6, 2023 accelerated share repurchase agreements

(e)The total number of shares delivered and the average price per share under the ASR agreements will be determined at the end of the ASR period

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

12 Months Ended

Dec. 31, 2023

Equity Method Investments and Joint Ventures [Abstract]

Summary NRG's equity method investments

The following table summarizes NRG's equity method investments as of December 31, 2023:

(In millions, except percentages)
Name:	Economic Interest		Investment Balance
Gladstone	37.5	%	$	34
Midway-Sunset Cogeneration Company	50.0	%	8
Total equity investments in affiliates			$	42

Undistributed earnings by equity investment

The following table summarizes the undistributed earnings from NRG's equity method investments as of December 31, 2023:

	As of December 31,
(In millions)	2023		2022
Undistributed earnings	$	—	$	42

Summary of Financial Information for Consolidated VIEs

The summarized financial information for the Company's consolidated VIEs consisted of the following:

(In millions)	December 31, 2023		December 31, 2022
Accounts receivable and Other current assets	$	1,541	$	2,108
Current liabilities	153		152
Net assets	$	1,388	$	1,956

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(Loss)/Income Per Share (Tables)

12 Months Ended

Dec. 31, 2023

Earnings Per Share [Abstract]

Reconciliation of NRG's basic and diluted income per share

The reconciliation of NRG's basic and diluted (loss)/income per share is shown in the following table:

	Year Ended December 31,
(In millions, except per share amounts)	2023		2022		2021
Basic and diluted (loss)/income per share:
Net (loss)/income	$	(202)	$	1,221	$	2,187
Less: Cumulative dividends attributable to Series A Preferred Stock	54		—		—
(Loss)/Income Available to Common Stockholders	$	(256)	$	1,221	$	2,187
Weighted average number of common shares outstanding - basic and diluted	228		236		245
(Loss)/Income per weighted average common share — basic and diluted	$	(1.12)	$	5.17	$	8.93

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Segment Reporting (Tables)

12 Months Ended

Dec. 31, 2023

Segment Reporting [Abstract]

Segment Reporting

	For the Year Ended December 31, 2023
(In millions)	Texas		East		West/Services/Other		Vivint Smart Home(a)		Corporate(b)		Eliminations		Total
Revenue(b)	$	10,476	$	12,547	$	4,281	$	1,549	$	—	$	(30)	$	28,823
Operating expenses	8,407		14,412		5,025		917		133		(30)		28,864
Depreciation and amortization	294		116		95		586		36		—		1,127
Impairment losses	2		4		20		—		—		—		26
Total operating cost and expenses	8,703		14,532		5,140		1,503		169		(30)		30,017
Gain on sale of assets	1,319		259		—		—		—		—		1,578
Operating income/(loss)	3,092		(1,726)		(859)		46		(169)		—		384
Equity in earnings of unconsolidated affiliates	—		—		16		—		—		—		16
Impairment losses on investments	—		—		(102)		—		—		—		(102)
Other income, net	2		11		6		(12)		56		(16)		47
Gain on debt extinguishment	—		—		—		—		109		—		109
Interest expense	(3)		(3)		(31)		(177)		(469)		16		(667)
Income/(loss) before income taxes	3,091		(1,718)		(970)		(143)		(473)		—		(213)
Income tax (benefit)/expense(c)	—		—		(111)		(32)		132		—		(11)
Net income/(loss)	$	3,091	$	(1,718)	$	(859)	$	(111)	$	(605)	$	—	$	(202)
Balance sheet
Equity investments in affiliates	$	—	$	—	$	42	$	—	$	—	$	—	$	42
Capital expenditures	495		5		27		18		53		—		598
Goodwill	643		721		221		3,494		—		—		5,079
Total assets	$	8,236	$	13,712	$	3,626	$	7,043	$	19,919	$	(26,498)	$	26,038

(a) Includes results of operations following the acquisition date of March 10, 2023
(b) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	5	$	9	$	16	$	—	$	—	$	—	$	30
(c) Consolidated domestic federal and state income taxes are recorded to the Corporate segment, except for Vivint Smart Home which is recorded directly to the Vivint Smart Home segment. West/Services/Other amounts represent foreign income taxes

	For the Year Ended December 31, 2022
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenue(a)	$	10,057	$	16,763	$	4,706	$	—	$	17	$	31,543
Operating expenses	8,495		16,031		4,108		86		17		28,737
Depreciation and amortization	310		208		85		31		—		634
Impairment losses	—		206		—		—		—		206
Total operating cost and expenses	8,805		16,445		4,193		117		17		29,577
Gain/(loss) on sale of assets	10		—		45		(3)		—		52
Operating income/(loss)	1,262		318		558		(120)		—		2,018
Equity in (losses)/earnings of unconsolidated affiliates	(2)		—		8		—		—		6
Other income, net	5		10		3		54		(16)		56
Interest expense	—		(1)		(32)		(400)		16		(417)
Income/(loss) before income taxes	1,265		327		537		(466)		—		1,663
Income tax expense(b)	—		1		57		384		—		442
Net income/(loss)	$	1,265	$	326	$	480	$	(850)	$	—	$	1,221
Balance sheet
Equity investments in affiliates	$	—	$	—	$	133	$	—	$	—	$	133
Capital expenditures	273		7		37		50		—		367
Goodwill	710		723		217		—		—		1,650
Total assets	$	11,475	$	19,526	$	8,139	$	35,780	$	(45,774)	$	29,146

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	4	$	(26)	$	5	$	—	$	—	$	(17)
(b) Consolidated domestic federal and state income taxes are recorded to the Corporate segment. West/Services/Other amounts represent foreign income taxes

	For the Year Ended December 31, 2021
(In millions)	Texas		East		West/Services/Other		Corporate(a)		Eliminations		Total
Revenue(a)	$	10,295	$	13,025	$	3,659	$	—	$	10	$	26,989
Operating expenses	8,692		10,256		3,467		141		10		22,566
Depreciation and amortization	336		333		88		28		—		785
Impairment losses	—		535		9		—		—		544
Total operating cost and expenses	9,028		11,124		3,564		169		10		23,895
Gain on sale of assets	19		—		17		211		—		247
Operating income	1,286		1,901		112		42		—		3,341
Equity in (losses)/earnings of unconsolidated affiliates	(3)		—		20		—		—		17
Other income, net	8		7		3		59		(14)		63
Loss on debt extinguishment	—		—		—		(77)		—		(77)
Interest expense	(1)		(1)		(28)		(469)		14		(485)
Income/(loss) before income taxes	1,290		1,907		107		(445)		—		2,859
Income tax expense(b)	—		—		19		653		—		672
Net income/(loss)	$	1,290	$	1,907	$	88	$	(1,098)	$	—	$	2,187

(a) Inter-segment sales and inter-segment net derivative gains and losses included in revenues	$	5	$	(18)	$	3	$	—	$	—	$	(10)
(b) Consolidated domestic federal and state income taxes are recorded to the Corporate segment. West/Services/Other amounts represent foreign income taxes

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2023

Income Tax Disclosure [Abstract]

Income tax provision from continuing operations

The income tax provision consisted of the following amounts:

	Year Ended December 31,
(In millions, except effective income tax rate)	2023			2022			2021
Current
U.S. Federal	$	26		$	3		$	—
State	84			65			48
Foreign	(12)			3			3
Total — current	98			71			51
Deferred
U.S. Federal	50			258			569
State	(61)			59			36
Foreign	(98)			54			16
Total — deferred	(109)			371			621
Total income tax (benefit)/expense	$	(11)		$	442		$	672
Effective income tax rate	5.2		%	26.6		%	23.5		%

Domestic and foreign components of income/(loss) before income tax (benefit)/expense

The following represented the domestic and foreign components of income before income taxes:

	Year Ended December 31,
(In millions)	2023		2022		2021
U.S.	$	261	$	1,436	$	2,759
Foreign	(474)		227		100
Total	$	(213)	$	1,663	$	2,859

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

Reconciliations of the U.S. federal statutory tax rate to NRG's effective tax rate were as follows:

	Year Ended December 31,
(In millions, except effective income tax rate)	2023			2022			2021
(Loss)/Income before income taxes	$	(213)		$	1,663		$	2,859
Tax at federal statutory tax rate	(45)			349			600
State taxes	(22)			69			111
Foreign rate differential	(10)			7			(3)
Changes in state valuation allowances	42			(3)			(29)
Permanent differences	31			17			8
Recognition of uncertain tax benefits	12			8			(10)
Deferred impact of state tax rate changes	3			14			(10)
Foreign tax refunds	(17)			—			—
Return to provision adjustments	(5)			—			5
Carbon capture tax credits	—			(19)			—
Income tax (benefit)/expense	$	(11)		$	442		$	672
Effective income tax rate	5.2		%	26.6		%	23.5		%

Company's deferred tax assets and liabilities

The temporary differences, which gave rise to the Company's deferred tax assets and liabilities consisted of the following:

	As of December 31,
(In millions)	2023		2022
Deferred tax assets:
U.S. Federal net operating loss carryforwards	$	1,762	$	1,717
State net operating loss carryforwards	367		315
Foreign net operating loss carryforwards	110		104
Deferred revenues	347		—
Difference between book and tax basis of property	353		399
Federal and state tax credit carryforwards	317		393
Deferred compensation, accrued vacation and other reserves	141		93
Interest disallowance carryforward per §163(j) of the Tax Act	132		65
Pension and other postretirement benefits	48		62
Allowance for credit losses	35		33
Equity compensation	24		8
Federal benefit on state uncertain tax positions	13		5
Inventory obsolescence	11		10
U.S. capital loss	1		15
Other	33		22
Total deferred tax assets	3,694		3,241
Deferred tax liabilities:
Intangibles amortization (excluding goodwill)	726		269
Derivatives	156		874
Capitalized contract costs	131		—
Equity method investments	93		82
Goodwill	40		26
Debt discount amortization	26		—
Emissions allowances	18		19
Total deferred tax liabilities	1,190		1,270
Total deferred tax assets less deferred tax liabilities	2,504		1,971
Valuation allowance	(275)		(224)
Total net deferred tax assets, net of valuation allowance	$	2,229	$	1,747

Summary of NRG's net deferred tax position

The following table summarizes NRG's net deferred tax position as presented in the consolidated balance sheets:

	As of December 31,
(In millions)	2023		2022
Deferred tax asset	$	2,251	$	1,881
Deferred tax liability	(22)		(134)
Net deferred tax asset	$	2,229	$	1,747

Reconciliation of total amounts of uncertain tax benefits

The following table summarizes uncertain tax benefits activity:

	As of December 31,
(In millions)	2023		2022
Balance as of January 1	$	22	$	13
Increase due to current year positions	28		9
Increase due to acquired balance from Vivint Smart Home	23		—
Uncertain tax benefits as of December 31	$	73	$	22

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Stock-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2023

Share-Based Payment Arrangement, Noncash Expense [Abstract]

Summary of Company's non-vested RSU awards and changes during the year

The following table summarizes the Company's non-vested RSU awards and changes during the year:

	Units	Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2022	856,917	$	40.25
Granted	1,031,469	35.71
Forfeited	(284,076)	34.70
Vested	(393,470)	39.67
Non-vested at December 31, 2023	1,210,840	37.88

Summary of Company's DSU awards and non-vested PSU Awards changes during the year

The following table summarizes the Company's outstanding DSU awards and changes during the year:

	Units	Weighted Average Grant Date Fair Value per Unit
Outstanding at December 31, 2022	418,014	$	27.63
Granted	79,072	34.40
Converted to Common Stock	(53,799)	25.11
Outstanding at December 31, 2023	443,287	29.07

The following table summarizes the Company's non-vested RPSU awards and changes during the year:

	Units	Weighted Average Grant-Date Fair Value per Unit
Non-vested at December 31, 2022	795,335	$	50.23
Granted	617,510	39.46
Forfeited(a)	(737,227)	45.61
Vested	(3,729)	50.28
Non-vested at December 31, 2023	671,889	46.27

(a)Includes January 2023 vestings that occurred at a 0% payout as well as forfeitures due to the departure of certain officers

Schedule of Assumptions used in Fair Value Model

Significant assumptions used in the fair value model with respect to the Company's RPSUs are summarized below:

	2023		2022		2021(a)
Expected volatility	41.35	%	37.54	%	34.05	%
Expected term (in years)	3		3		3
Risk free rate	4.18	%	0.97	%	0.17	%

(a)Assumptions pertain to the main award granted in January 2021. Additional 60,815 RPSUs were granted in September 2021 with a risk free rate of 0.42% and expected volatility of 37.38%

Summary of NRG's total compensation expense recognized and total non-vested compensation costs not yet recognized and the period over which this expense is expected to be recognized

The following table summarizes NRG's total compensation expense recognized for the years presented, as well as total non-vested compensation costs not yet recognized and the period over which this expense is expected to be recognized as of December 31, 2023, for each of the types of awards issued under the LTIPs. Minimum tax withholdings of $22 million, $6 million, and $9 million for the years ended December 31, 2023, 2022, and 2021, respectively, are reflected as a reduction to additional paid-in capital on the Company's consolidated balance sheets.

							Non-vested Compensation Cost
(In millions, except weighted average data)	Compensation Expense						Unrecognized Total Cost		Weighted Average Recognition Period Remaining (In years)
	Year Ended December 31,						As of December 31,
Award	2023		2022		2021		2023		2023
RSUs under NRG LTIP	$	20	$	15	$	9	$	29	1.61
RSUs under Vivint LTIP	76		—		—		69		1.82
PSUs under Vivint LTIP	2		—		—		3		2.25
DSUs	2		2		2		—		0.00
RPSUs	3		11		9		17		1.69
PRSUs under NRG LTIP(a)	12		6		7		15		1.74
PRSUs under Vivint LTIP(a)	8		—		—		14		2.29
Total	$	123	$	34	$	27	$	147
Tax detriment recognized	$	2	$	3	$	2

(a)Phantom Restricted Stock Units, PRSUs, are liability-classified time-based awards that typically vest ratably over a three-year period. The amount to be paid upon vesting is based on NRG's closing stock price for the period

Summary of Non-vested RSUs Under Vivint LTIP

The following table summarizes the non-vested RSUs under the Vivint LTIP and changes during the year:

	Rollover RSUs			RSUs granted following the Acquisition
	Units	Weighted Average Grant Date Fair Value per Unit		Units	Weighted Average Grant Date Fair Value per Unit
Non-vested at December 31, 2022	—	$	—	—	$	—
Rollover RSUs at the Acquisition date	4,553,998	31.63		—	—
Granted following the Acquisition date	—	—		895,827	35.24
Forfeited	(288,776)	31.63		(110,531)	35.21
Vested	(1,280,321)	31.63		(4,998)	35.21
Non-vested at December 31, 2023	2,984,901	31.63		780,298	35.24

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Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2023

Related Party Transactions [Abstract]

Summary of NRG's material related-party transactions with affiliates

The following table summarizes NRG's material related party transactions with third-party affiliates:

	Year Ended December 31,
(In millions)	2023		2022		2021
Revenues from Related Parties Included in Revenues
Gladstone	$	4	$	4	$	4
Ivanpah(a)	78		42		39
Midway-Sunset	2		6		6
Total	$	84	$	52	$	49

(a)Includes fees under project management agreements with each project company

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Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

Minimum Commitments Under Outstanding Agreements

As of December 31, 2023, the Company's minimum commitments under such outstanding agreements are estimated as follows:

Period	(In millions)
2024	$	573
2025	836
2026	540
2027	364
2028	292
Thereafter	823
Total(a)	$	3,428

(a)The year 2024 does not include an additional $978 million of short-term commitments

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Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2023

Supplemental Cash Flow Information [Abstract]

Details of supplemental disclosures of cash flow and non-cash investing and financing information

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

	Year Ended December 31,
(In millions)	2023		2022		2021
Cash and cash equivalents	$	541	$	430	$	250
Funds deposited by counterparties	84		1,708		845
Restricted cash	24		40		15
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$	649	$	2,178	$	1,110

Detail of supplemental disclosures of cash flow and non-cash investing and financing information was:

	Year Ended December 31,
(In millions)	2023		2022		2021
Interest paid, net of amount capitalized	$	548	$	383	$	433
Income taxes paid, net of refunds	48		66		32
Non-cash investing activities:
Decreases to fixed assets for accrued capital expenditures	—		(68)		(16)

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Guarantees (Tables)

12 Months Ended

Dec. 31, 2023

Guarantees [Abstract]

Summary of maximum potential exposure that can be estimated by NRG's guarantees, indemnity, and other contingent liability

The following table summarizes the maximum potential exposures that can be estimated for NRG's guarantees, indemnities, and other contingent liabilities by maturity:

	By Remaining Maturity at December 31,
(In millions)	2023
Guarantees	Under 1 Year		1-3 Years		3-5 Years		Over 5 Years		Total		2022 Total
Letters of credit and surety bonds	$	4,555	$	37	$	—	$	—	$	4,592	$	5,211
Asset sales guarantee obligations	13		24		22		67		126		409
Other guarantees	—		—		—		27		27		15
Total guarantees	$	4,568	$	61	$	22	$	94	$	4,745	$	5,635

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Jointly Owned Plant (Tables)

12 Months Ended

Dec. 31, 2023

Jointly Owned Plants Disclosure [Abstract]

Summary of NRG's proportionate ownership interest in the company's jointly-owned facilities

The following table summarizes NRG's proportionate ownership interest in the Company's jointly-owned facility:

(In millions unless otherwise stated)
As of December 31, 2023	Ownership Interest		Property, Plant & Equipment		Accumulated Depreciation		Construction in Progress
Cedar Bayou Unit 4, Baytown, TX	50.00	%	$	222	$	(115)	$	2

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Nature of Business (Details) customer in Millions	12 Months Ended
	Dec. 31, 2023 customer MW
Business Acquisition [Line Items]
Generation capacity (in MW) | MW	13
Home
Business Acquisition [Line Items]
Customers served | customer	8

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Summary of Significant Accounting Policies - Error Correction (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Proceeds from credit facilities	$ 3,020	$ 0	$ 1,415
Repayments to credit facilities	$ 3,020	$ 0	1,415
Error Correction
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Proceeds from credit facilities			1,400
Repayments to credit facilities			$ 1,400

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Summary of Significant Accounting Policies - Narrative (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Securitization Proceeds [Abstract]
Proceeds from ERCOT	$ 689
Funds Deposited by Counterparties
Number of months beyond which company can not predict the holding of collateral (in months)		12 months
Loss Contingency [Abstract]
Insurance settlement		$ 7	$ 81
Finite-Lived Intangible Assets, Net [Abstract]
Intangible assets, accumulated amortization		$ 2,994	2,112
Capitalized Contract Cost [Abstract]
Contract with customer, term		5 years
Gross Receipts and Sales Taxes
Gross receipts taxes		$ 212	218	$ 184
Purchased Energy and Other Cost of Sales for Customer Operations
Transmission and distribution charges not yet billed		240	202	189
Foreign Currency Translation and Transaction Gains and Losses
Cumulative translation adjustment		(43)	(55)	(8)
Marketing and Advertising Costs
Advertising expense		$ 185	$ 82	$ 109

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Summary of Significant Accounting Policies - Activity in the Allowance for Credit Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance	$ 133	$ 683	$ 67
Provision for credit losses	251	11	698
Write-offs	(313)	(593)	(224)
Recoveries collected	39	32	30
Other	13	0	0
Ending balance	145	133	683
Provision for credit losses (decrease) increase due finance hedge risk		(70)	403
Vivint Smart Home
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Acquired balance	22	0	0
Direct Energy
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Acquired balance	$ 0	$ 0	$ 112

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Summary of Significant Accounting Policies - Credit Losses Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Summary of Significant Accounting Policies [Line Items]
Provision (income) for credit losses	$ 251	$ 11	$ 698
Winter Storm Uri
Summary of Significant Accounting Policies [Line Items]
Provision (income) for credit losses		$ (126)	$ 596

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Summary of Significant Accounting Policies - Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Accounting Policies [Abstract]
Cash and cash equivalents	$ 541	$ 430	$ 250
Funds deposited by counterparties	84	1,708	845
Restricted cash	24	40	15
Cash and cash equivalents, funds deposited by counterparties and restricted cash shown in the statements of cash flows	$ 649	$ 2,178	$ 1,110	$ 3,930

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Summary of Significant Accounting Policies - Vivint Flex Pay and Capitalized Contract Costs (Details) - Vivint Smart Home	12 Months Ended
	Dec. 31, 2023 performanceObligation
Product Information [Line Items]
Customer, short-term financing term	6 months
Number of performance obligations	1
Minimum
Product Information [Line Items]
Customer repayment terms	6 months
Liability for customer lost principal balances, percentage	2.60%
Maximum
Product Information [Line Items]
Customer repayment terms	60 months
Liability for customer lost principal balances, percentage	100.00%

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Revenue Recognition - Retail Revenue (Details)	12 Months Ended
	Dec. 31, 2023
Vivint Home Services Retail Revenue
Disaggregation of Revenue [Line Items]
Payment terms	30 days
Minimum | Retail Revenue
Disaggregation of Revenue [Line Items]
Payment terms	15 days
Minimum | Energy Revenue
Disaggregation of Revenue [Line Items]
Payment terms	5 days
Minimum | Capacity Revenue
Disaggregation of Revenue [Line Items]
Payment terms	15 days
Maximum | Retail Revenue
Disaggregation of Revenue [Line Items]
Payment terms	60 days
Maximum | Vivint Home Services Retail Revenue
Disaggregation of Revenue [Line Items]
Expected period of benefit	five years
Maximum | Energy Revenue
Disaggregation of Revenue [Line Items]
Payment terms	55 days
Maximum | Capacity Revenue
Disaggregation of Revenue [Line Items]
Payment terms	55 days

XML

Revenue Recognition - Performance Obligations (Details) $ in Millions	Dec. 31, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Estimated future fixed fee performance obligation	$ 1,400
Revenue, remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Estimated future fixed fee performance obligation	$ 1,000
Revenue, remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Estimated future fixed fee performance obligation	$ 756
Revenue, remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Estimated future fixed fee performance obligation	$ 468
Revenue, remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Estimated future fixed fee performance obligation	$ 176
Revenue, remaining performance obligation, period	1 year

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Revenue Recognition - Disaggregated Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	$ 28,256	$ 31,488	$ 26,777
Mark-to-market for economic hedging activities	(2,863)	1,248	2,716
Contract amortization	(168)	(86)	(95)
Revenues	28,823	31,543	26,989
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	52	35	(22)
Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	74	110
Retail Revenue | Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	12,171	10,761	9,549
Retail Revenue | Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	15,296	18,961	14,012
Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	27,467	29,722	23,561
Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	553	1,250	1,215
Derivative revenue	176	(8)	136
Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	197	272	775
Derivative revenue	73	33	149
Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	144	(83)	(164)
Less: Realized and unrealized ASC 815 revenue	515	20	234
Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	494	421	1,632
Contract amortization	(32)	(39)	(30)
Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	28,823	31,543	26,989
Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	48	(32)	113
Corporate/Eliminations
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(14)	(15)	(6)
Revenues	(30)	17	10
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	0	1	0
Corporate/Eliminations | Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0	0
Corporate/Eliminations | Retail Revenue | Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(1)	(1)	(1)
Corporate/Eliminations | Retail Revenue | Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0
Corporate/Eliminations | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(1)	(1)	(1)
Corporate/Eliminations | Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	32	7
Derivative revenue	1	31	3
Corporate/Eliminations | Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(2)	0	0
Derivative revenue	0	0	0
Corporate/Eliminations | Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	(16)	1	13
Less: Realized and unrealized ASC 815 revenue	(16)	31	16
Corporate/Eliminations | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(11)	(15)	(9)
Contract amortization	0	0	0
Corporate/Eliminations | Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	(30)	17	10
Corporate/Eliminations | Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	(1)	(1)	0
Texas | Operating Segments
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	10,447	10,059	10,165
Revenues	10,476	10,057	10,295
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	0	0	0
Texas | Operating Segments | Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0	0
Texas | Operating Segments | Retail Revenue | Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	6,538	6,388	5,659
Texas | Operating Segments | Retail Revenue | Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	3,492	3,229	2,745
Texas | Operating Segments | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	10,030	9,617	8,404
Texas | Operating Segments | Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	77	111	329
Derivative revenue	0	0	0
Texas | Operating Segments | Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0
Derivative revenue	0	0	0
Texas | Operating Segments | Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	0	2	(3)
Less: Realized and unrealized ASC 815 revenue	29	(2)	130
Texas | Operating Segments | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	369	327	1,565
Contract amortization	0	0	0
Texas | Operating Segments | Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	10,476	10,057	10,295
Texas | Operating Segments | Other ancillary revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer			1,300
Texas | Operating Segments | Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	29	(4)	133
Texas | Corporate/Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(5)	(4)	(5)
East | Operating Segments
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	12,166	16,686	12,866
Revenues	12,547	16,763	13,025
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	17	(7)	(25)
East | Operating Segments | Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	74	110
East | Operating Segments | Retail Revenue | Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	2,195	2,088	1,832
East | Operating Segments | Retail Revenue | Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	9,751	13,768	10,030
East | Operating Segments | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	11,946	15,856	11,862
East | Operating Segments | Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	291	641	508
Derivative revenue	162	(31)	131
East | Operating Segments | Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	197	232	718
Derivative revenue	73	33	149
East | Operating Segments | Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	57	(30)	(88)
Less: Realized and unrealized ASC 815 revenue	364	84	184
East | Operating Segments | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	88	104	51
Contract amortization	(32)	(40)	(26)
East | Operating Segments | Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	12,547	16,763	13,025
East | Operating Segments | Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	(2)	2	(8)
East | Corporate/Eliminations
Disaggregation of Revenue [Line Items]
Revenues	(9)	26	18
West/Services/Other | Operating Segments
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	4,108	4,758	3,752
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	35	41	3
West/Services/Other | Operating Segments | Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0	0
West/Services/Other | Operating Segments | Retail Revenue | Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,890	2,286	2,059
West/Services/Other | Operating Segments | Retail Revenue | Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	2,053	1,964	1,237
West/Services/Other | Operating Segments | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	3,943	4,250	3,296
West/Services/Other | Operating Segments | Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	185	466	371
Derivative revenue	13	(8)	2
West/Services/Other | Operating Segments | Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	2	40	57
Derivative revenue	0	0	0
West/Services/Other | Operating Segments | Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	103	(56)	(86)
Less: Realized and unrealized ASC 815 revenue	138	(93)	(96)
West/Services/Other | Operating Segments | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	48	5	25
Contract amortization	0	1	(4)
West/Services/Other | Operating Segments | Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	4,281	4,706	3,659
West/Services/Other | Operating Segments | Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	22	$ (29)	$ (12)
Vivint Smart Home | Operating Segments
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,549
Revenues	1,549
Less: Revenues accounted for under topics other than ASC 606 and ASC 815	0
Vivint Smart Home | Operating Segments | Retail Revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0
Vivint Smart Home | Operating Segments | Retail Revenue | Home
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,549
Vivint Smart Home | Operating Segments | Retail Revenue | Business
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0
Vivint Smart Home | Operating Segments | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,549
Vivint Smart Home | Operating Segments | Energy revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0
Derivative revenue	0
Vivint Smart Home | Operating Segments | Capacity revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0
Derivative revenue	0
Vivint Smart Home | Operating Segments | Derivative revenue
Disaggregation of Revenue [Line Items]
Mark-to-market for economic hedging activities	0
Less: Realized and unrealized ASC 815 revenue	0
Vivint Smart Home | Operating Segments | Other revenue
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0
Contract amortization	0
Vivint Smart Home | Operating Segments | Total operating revenues
Disaggregation of Revenue [Line Items]
Revenues	1,549
Vivint Smart Home | Operating Segments | Other derivative revenue
Disaggregation of Revenue [Line Items]
Derivative revenue	0
Vivint Smart Home | Corporate/Eliminations
Disaggregation of Revenue [Line Items]
Revenues	$ 0

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Revenue Recognition - Contract Balances (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Schedule Of Contract Assets And Liabilities [Line Items]
Capitalized contract costs	$ 706	$ 126
Accounts receivable, net	3,542	4,773
Unbilled revenues (included within Accounts receivable, net - Contracts with customers)	1,493	1,952
Deferred revenue	1,634	186
Capitalized contract amortization	168	86	$ 95
Deferred revenue from contract with customers	1,600	175
Accounts receivable, net - Contracts with customers
Schedule Of Contract Assets And Liabilities [Line Items]
Accounts receivable, net	3,395	4,704
Accounts receivable, net - Accounted for under topics other than ASC 606
Schedule Of Contract Assets And Liabilities [Line Items]
Accounts receivable, net	136	64
Accounts receivable, net - Affiliate
Schedule Of Contract Assets And Liabilities [Line Items]
Accounts receivable, net	$ 11	$ 5

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Revenue Recognition - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Schedule Of Contract Assets And Liabilities [Line Items]
Revenue recognized	$ 168	$ 184
Contract with customer, term	5 years
Capitalized Contract Cost, Amortization Period	5 years
Minimum | Vivint Smart Home
Schedule Of Contract Assets And Liabilities [Line Items]
Contract with customer, term	3 years
Maximum | Vivint Smart Home
Schedule Of Contract Assets And Liabilities [Line Items]
Contract with customer, term	5 years

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Acquisitions and Dispositions - Acquisitions (Details)			1 Months Ended	12 Months Ended
	Mar. 10, 2023 USD ($) customer $ / shares	Jan. 05, 2021 USD ($) state province customer	Feb. 28, 2023 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Mar. 09, 2023 USD ($)
Business Acquisition [Line Items]
Proceeds from issuance of long-term debt				$ 731,000,000	$ 0	$ 1,100,000,000
Proceeds from issuance of preferred stock, net of fees				635,000,000	0	0
Issuance of Series A Preferred Stock				635,000,000
Proceeds from credit facilities				3,020,000,000	$ 0	1,415,000,000
Canada
Business Acquisition [Line Items]
Provinces in which entity operates | province		8
Customer Relationships
Business Acquisition [Line Items]
Weighted average useful life, years					6 years
Senior Secured First Lien Notes, due 2033 | Senior Notes
Business Acquisition [Line Items]
Aggregate principal amount							$ 740,000,000
Interest rate, stated percentage							7.00%
Vivint
Business Acquisition [Line Items]
Customers | customer	2,000,000
Acquisition, share price (in usd per share) | $ / shares	$ 12
Cash paid to acquire business	$ 2,609,000,000
Acquisition costs				$ 38,000,000	$ 17,000,000
Total consideration	$ 2,623,000,000
Weighted average useful life, years	10 years
Aggregate principal of debt acquired	$ 2,700,000,000
Amortization of remaining term of debt	$ 152,000,000
Vivint | Customer Relationships
Business Acquisition [Line Items]
Weighted average useful life, years	12 years
Vivint | Technology
Business Acquisition [Line Items]
Weighted average useful life, years	5 years
Vivint | Trade Names
Business Acquisition [Line Items]
Weighted average useful life, years	10 years
Vivint | Revolving Credit Facility
Business Acquisition [Line Items]
Proceeds from credit facilities	$ 900,000,000
Increase in existing borrowing commitments			$ 600,000,000
Vivint | Series A Preferred Stock
Business Acquisition [Line Items]
Proceeds from issuance of preferred stock, net of fees	635,000,000
Issuance of Series A Preferred Stock	$ 650,000,000
Preferred stock, dividend rate (as percent)	10.25%
Vivint | Senior Secured First Lien Notes, due 2033 | Senior Notes
Business Acquisition [Line Items]
Proceeds from issuance of long-term debt	$ 724,000,000
Aggregate principal amount	$ 740,000,000
Interest rate, stated percentage	7.00%
Direct Energy
Business Acquisition [Line Items]
Customers | customer		3,000,000
Acquisition costs						$ 25,000,000
Total consideration		$ 3,625,000,000
Purchase price adjustment		99,000,000
Adjusted purchase price		$ 3,724,000,000
Direct Energy | U.S.
Business Acquisition [Line Items]
Number of states in which the entity operates | state		50
Direct Energy | Customer Relationships
Business Acquisition [Line Items]
Weighted average useful life, years		12 years
Direct Energy | Trade Names
Business Acquisition [Line Items]
Weighted average useful life, years		12 years

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Acquisitions and Dispositions - Consideration (Details) $ / shares in Units, $ in Millions	Mar. 10, 2023 USD ($) $ / shares shares
Business Acquisition [Line Items]
Acquisition, shares outstanding (in shares) | shares	216,901,639
Vivint
Business Acquisition [Line Items]
Acquisition, share price (in usd per share) | $ / shares	$ 12
Vivint Smart Home, Inc. common shares outstanding as of March 10, 2023 of 216,901,639 at $12.00 per share	$ 2,603
Other Vivint Smart Home, Inc. equity instruments (Cash out RSUs and PSUs, Stock Appreciation Rights, Private Placement Warrants)	6
Total Cash Consideration	2,609
Total Consideration	2,623
Vivint | Equity Awards Pre-combination Service
Business Acquisition [Line Items]
Fair value of acquired Vivint Smart Home, Inc. equity awards attributable to pre-combination service	$ 14

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Acquisitions and Dispositions - Vivint Purchase Price Allocation (Details) - USD ($)		12 Months Ended
	Mar. 10, 2023	Dec. 31, 2022	Dec. 31, 2023	Dec. 31, 2021
Other Assets
Goodwill		$ 1,650,000,000	$ 5,079,000,000	$ 1,795,000,000
Customer Relationships
Other Liabilities
Weighted average useful life, years		6 years
Vivint
Current Assets
Cash and cash equivalents	$ 120,000,000
Accounts receivable, net	60,000,000
Inventory	113,000,000
Prepayments and other current assets	37,000,000
Total current assets	330,000,000
Property, plant and equipment, net	49,000,000
Other Assets
Operating lease right-of-use assets, net	35,000,000
Goodwill	3,494,000,000
Intangible assets	2,770,000,000
Deferred income taxes	382,000,000
Other non-current assets	14,000,000
Total other assets	6,695,000,000
Total Assets	7,074,000,000
Current Liabilities
Current portion of long-term debt and finance leases	14,000,000
Current portion of operating lease liabilities	13,000,000
Accounts payable	109,000,000
Derivatives instruments	80,000,000
Deferred revenue current	518,000,000
Accrued expenses and other current liabilities	207,000,000
Total current liabilities	941,000,000
Other Liabilities
Long-term debt and finance leases	2,572,000,000
Non-current operating lease liabilities	28,000,000
Derivative instruments	32,000,000
Deferred income taxes	18,000,000
Deferred revenue non-current	837,000,000
Other non-current liabilities	23,000,000
Total other liabilities	3,510,000,000
Total Liabilities	4,451,000,000
Direct Energy Purchase Price	2,623,000,000
Goodwill, expected to be tax deductible	$ 0
Weighted average useful life, years	10 years
Vivint | Customer Relationships
Other Assets
Intangible assets	$ 1,740,000,000
Other Liabilities
Weighted average useful life, years	12 years
Vivint | Technology
Other Assets
Intangible assets	$ 860,000,000
Other Liabilities
Weighted average useful life, years	5 years
Vivint | Trade Names
Other Assets
Intangible assets	$ 160,000,000
Other Liabilities
Weighted average useful life, years	10 years
Vivint | Sales channel contract
Other Assets
Intangible assets	$ 10,000,000

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Acquisitions and Dispositions - Supplemental Pro Forma Financial Information (Details) - Vivint - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Business Acquisition [Line Items]
Total operating revenues	$ 29,109	$ 33,225	$ 28,468
Net (loss)/income	$ (3)	$ 1,136	$ 1,574

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Acquisitions and Dispositions - Direct Energy Purchase Price Allocation (Details) - USD ($) $ in Millions		12 Months Ended
	Jan. 05, 2021	Dec. 31, 2022	Dec. 31, 2023	Dec. 31, 2021
Other Assets
Goodwill		$ 1,650	$ 5,079	$ 1,795
Texas
Other Assets
Goodwill		710	643	716
East
Other Assets
Goodwill		$ 723	$ 721	$ 853
Customer Relationships
Other Liabilities
Weighted average useful life, years		6 years
Direct Energy
Current Assets
Cash and cash equivalents		$ 152
Funds deposited by counterparties		21
Restricted cash		9
Accounts receivable, net		1,802
Inventory		106
Derivative instruments		1,014
Cash collateral paid in support of energy risk management activities		233
Prepayments and other current assets		173
Total current assets		3,510
Property, plant and equipment, net		151
Other Assets
Goodwill		1,250
Intangible assets		2,321
Derivative instruments		531
Other non-current assets		31
Total other assets		4,133
Total Assets		7,794
Current Liabilities
Accounts payable		1,116
Derivative instruments		1,266
Cash collateral received in support of energy risk management activities		21
Accrued expenses and other current liabilities		670
Total current liabilities		3,073
Other Liabilities
Derivative instruments		562
Deferred income taxes		320
Other non-current liabilities		115
Total other liabilities		997
Total Liabilities		4,070
Direct Energy Purchase Price		3,724
Goodwill, expected to be tax deductible		322
Direct Energy | Texas
Other Assets
Goodwill		427
Direct Energy | East
Other Assets
Goodwill		648
Direct Energy | West/Services/Other
Other Assets
Goodwill		175
Direct Energy | Customer Relationships
Other Assets
Intangible assets		1,277
Other Liabilities
Weighted average useful life, years	12 years
Direct Energy | Customer and Supply Contracts
Other Assets
Intangible assets		610
Other Liabilities
Weighted average useful life, years	12 years
Direct Energy | Trade Names
Other Assets
Intangible assets		310
Other Liabilities
Weighted average useful life, years	12 years
Direct Energy | Renewables Energy Certificates
Other Assets
Intangible assets		$ 124
Other Liabilities
Weighted average useful life, years	12 years

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Acquisitions and Dispositions - Dispositions Narrative (Details) $ in Millions	Nov. 01, 2023 USD ($)	Oct. 02, 2023 USD ($)	Jan. 06, 2023 USD ($)	Jun. 01, 2022 USD ($)	Dec. 01, 2021 USD ($) MW	Feb. 03, 2021 USD ($)	Dec. 31, 2023 MW
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Generation capacity (in MW) | MW							13
Disposal Group, Not Discontinued Operation, Gain Loss on Disposal Statement of Income Extensible List Not Disclosed Flag		82 million
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations | Indemnification Agreement
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Guarantee (up to)					$ 39
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations | Agua Caliente Solar Project
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale						$ 202
Gain on sale						$ 17
Percentage of ownership sold						35.00%
Cash disposed						$ 7
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Gregory
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale		$ 102
Gain on sale		$ 82
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Gregory | Gregory
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage, parent		100.00%
East | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of land and related generation assets			$ 212
Transaction fees on disposal			3
Gain on sale of land and related generation assets			$ 199
East/West Other | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale					760
Working capital adjustments					140
Proceeds from sale of, net of working capital adjustments					$ 620
Generation capacity (in MW) | MW					4,850
Gain (loss) on sale of business					$ 207
STP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage	44.00%						44.00%
STP | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage	44.00%
Proceeds from sale	$ 1,750
Working capital adjustments	96
Proceeds from sale of, net of working capital adjustments	1,654
Gain on sale	$ 1,200
Watson Facility
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage				49.00%
Proceeds from sale of investment				$ 59
Gain on sale of investment				$ 46
Arthur Kill Plant | East/West Other
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Generation capacity (in MW) | MW					866

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Acquisitions and Dispositions - Income Before Income Taxes From Equity Interest in STP (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income before income taxes	$ 16	$ 6	$ 17
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations | STP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income before income taxes	$ 206	$ 362	$ 829

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Fair Value of Financial Instruments - Estimated Carrying Amounts and Fair Value of Long-term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Liabilities
Long-term debt	$ 10,940	$ 8,100
Carrying Amount
Liabilities
Long-term debt	10,794	8,098
Carrying Amount | Convertible Senior Notes
Liabilities
Long-term debt	575	575
Carrying Amount | Other Debt Obligations
Liabilities
Long-term debt	10,219	7,523
Fair Value
Liabilities
Long-term debt	10,574	7,008
Fair Value | Convertible Senior Notes
Liabilities
Long-term debt	739	576
Fair Value | Other Debt Obligations
Liabilities
Long-term debt	$ 9,835	$ 6,432

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Fair Value of Financial Instruments - Assets and Liabilities Measured and Recorded at Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	$ 21	$ 19
Other trust fund investments (classified within other non-current assets):
Other trust fund investments		1
Measured using net asset value practical expedient:
Total assets	6,182	12,858
Derivative liabilities:
Total liabilities	5,507	8,441
Interest rate contracts
Derivative assets:
Derivative Assets	12
Derivative liabilities:
Derivative liabilities	8
Foreign exchange contract
Derivative assets:
Derivative Assets	5	18
Derivative liabilities:
Derivative liabilities	9	2
Commodity contracts
Derivative assets:
Derivative Assets	6,138	11,976
Derivative liabilities:
Derivative liabilities	5,356	8,439
Consumer Financing Program
Derivative liabilities:
Derivative liabilities	134
Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments		15
U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments		86
Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		101
Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		35
Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments		114
Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments		403
Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments		1
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	0	0
Other trust fund investments (classified within other non-current assets):
Other trust fund investments		1
Measured using net asset value practical expedient:
Total assets	1,334	2,432
Derivative liabilities:
Total liabilities	1,413	1,244
Level 1 | Interest rate contracts
Derivative assets:
Derivative Assets	0
Derivative liabilities:
Derivative liabilities	0
Level 1 | Foreign exchange contract
Derivative assets:
Derivative Assets	0	0
Derivative liabilities:
Derivative liabilities	0	0
Level 1 | Commodity contracts
Derivative assets:
Derivative Assets	1,334	1,929
Derivative liabilities:
Derivative liabilities	1,413	1,244
Level 1 | Consumer Financing Program
Derivative liabilities:
Derivative liabilities	0
Level 1 | Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments		15
Level 1 | U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments		84
Level 1 | Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 1 | Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 1 | Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 1 | Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments		403
Level 1 | Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	21	19
Other trust fund investments (classified within other non-current assets):
Other trust fund investments		0
Measured using net asset value practical expedient:
Total assets	4,508	9,086
Derivative liabilities:
Total liabilities	3,745	6,451
Level 2 | Interest rate contracts
Derivative assets:
Derivative Assets	12
Derivative liabilities:
Derivative liabilities	8
Level 2 | Foreign exchange contract
Derivative assets:
Derivative Assets	5	18
Derivative liabilities:
Derivative liabilities	9	2
Level 2 | Commodity contracts
Derivative assets:
Derivative Assets	4,470	8,796
Derivative liabilities:
Derivative liabilities	3,728	6,449
Level 2 | Consumer Financing Program
Derivative liabilities:
Derivative liabilities	0
Level 2 | Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 2 | U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments		2
Level 2 | Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		101
Level 2 | Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		35
Level 2 | Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments		114
Level 2 | Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 2 | Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments		1
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments in securities (classified within other current and non-current assets)	0	0
Other trust fund investments (classified within other non-current assets):
Other trust fund investments		0
Measured using net asset value practical expedient:
Total assets	334	1,251
Derivative liabilities:
Total liabilities	349	746
Level 3 | Interest rate contracts
Derivative assets:
Derivative Assets	0
Derivative liabilities:
Derivative liabilities	0
Level 3 | Foreign exchange contract
Derivative assets:
Derivative Assets	0	0
Derivative liabilities:
Derivative liabilities	0	0
Level 3 | Commodity contracts
Derivative assets:
Derivative Assets	334	1,251
Derivative liabilities:
Derivative liabilities	215	746
Level 3 | Consumer Financing Program
Derivative liabilities:
Derivative liabilities	134
Level 3 | Cash and cash equivalents
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 3 | U.S. government and federal agency obligations
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 3 | Federal agency mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 3 | Commercial mortgage-backed securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 3 | Corporate debt securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 3 | Equity securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Level 3 | Foreign government fixed income securities
Nuclear trust fund investments:
Nuclear trust fund investments		0
Net Asset Value | Equity securities
Measured using net asset value practical expedient:
Equity securities	$ 6	6
Net Asset Value | Equity securities - nuclear trust fund investments
Measured using net asset value practical expedient:
Equity securities		$ 83

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Fair Value of Financial Instruments - Reconciliation of Level 3 Financial Instruments (Details) - Level 3 - Derivative - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 505	$ 293
Total (losses)/gains realized/unrealized included in earnings	(164)	53
Purchases	42	(110)
Transfers into Level 3	78	264
Transfers out of Level 3	(342)	5
Ending balance	119	505
(Losses)/gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets or liabilities still held as of year-end	$ (46)	$ 204

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Fair Value of Financial Instruments - Contractual Obligations From the Consumer Financing Program (Details) - Level 3 - Derivative - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 505	$ 293
New contractual obligations	(42)	110
Total losses included in earnings	164	(53)
Ending balance	119	505
Consumer Financing Program
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	0
Contractual obligations added from the acquisition of Vivint Smart Home	(112)
New contractual obligations	(68)
Settlements	62
Total losses included in earnings	(16)
Ending balance	$ (134)	$ 0

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Fair Value of Financial Instruments - Derivative Fair Value Measurements Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Total derivative assets valued with prices provided by models and other valuation techniques percentage	5.00%
Total derivative liabilities valued with prices provided by models and other valuation techniques, percentage	6.00%
Change in credit reserve	$ 18	$ 9

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Fair Value of Financial Instruments - Significant Unobservable Inputs Used in Fair Value of Level 3 Positions (Details) $ in Millions	Dec. 31, 2023 USD ($) certificate $ / MWd $ / MMBTU $ / MWh	Dec. 31, 2022 USD ($) $ / MWh
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Cash collateral paid in support of energy risk management activities	$ 441	$ 260
Cash collateral received in support of energy risk management activities	84	1,708
Fair Value, Measurements, Recurring | Renewables Energy Certificates | Level 3
Assets
Derivative Assets	58
Liabilities
Derivative Liabilities	$ 14
Fair Value, Measurements, Recurring | Renewables Energy Certificates | Level 3 | Low | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | certificate	2
Fair Value, Measurements, Recurring | Renewables Energy Certificates | Level 3 | High | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | certificate	320
Fair Value, Measurements, Recurring | Renewables Energy Certificates | Level 3 | Weighted Average | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | certificate	15,000,000
Commodity contracts
Assets
Derivative Assets	$ 6,138	11,976
Liabilities
Derivative Liabilities	5,356	8,439
Commodity contracts | Level 3
Assets
Derivative Assets	334	1,251
Liabilities
Derivative Liabilities	215	746
Commodity contracts | Natural Gas Contracts | Level 3
Assets
Derivative Assets		340
Liabilities
Derivative Liabilities		$ 448
Commodity contracts | Natural Gas Contracts | Level 3 | Low
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		2
Commodity contracts | Natural Gas Contracts | Level 3 | High
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		48
Commodity contracts | Natural Gas Contracts | Level 3 | Weighted Average
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		6
Commodity contracts | Fair Value, Measurements, Recurring | Level 3
Assets
Derivative Assets	334	$ 1,251
Liabilities
Derivative Liabilities	349	746
Commodity contracts | Fair Value, Measurements, Recurring | Natural Gas Contracts | Level 3
Assets
Derivative Assets	39
Liabilities
Derivative Liabilities	$ 65
Commodity contracts | Fair Value, Measurements, Recurring | Natural Gas Contracts | Level 3 | Low | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MMBTU	1
Commodity contracts | Fair Value, Measurements, Recurring | Natural Gas Contracts | Level 3 | High | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MMBTU	15
Commodity contracts | Fair Value, Measurements, Recurring | Natural Gas Contracts | Level 3 | Weighted Average | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MMBTU	3,000,000
Commodity contracts | Fair Value, Measurements, Recurring | Power Contracts | Level 3
Assets
Derivative Assets	$ 197	843
Liabilities
Derivative Liabilities	$ 66	$ 216
Commodity contracts | Fair Value, Measurements, Recurring | Power Contracts | Level 3 | Low
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		3
Commodity contracts | Fair Value, Measurements, Recurring | Power Contracts | Level 3 | Low | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh	1
Commodity contracts | Fair Value, Measurements, Recurring | Power Contracts | Level 3 | High
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		431
Commodity contracts | Fair Value, Measurements, Recurring | Power Contracts | Level 3 | High | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh	210
Commodity contracts | Fair Value, Measurements, Recurring | Power Contracts | Level 3 | Weighted Average
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		48
Commodity contracts | Fair Value, Measurements, Recurring | Power Contracts | Level 3 | Weighted Average | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh	47,000,000
Commodity contracts | Fair Value, Measurements, Recurring | FTRs | Level 3
Assets
Derivative Assets	$ 19	$ 68
Liabilities
Derivative Liabilities	$ 37	$ 82
Commodity contracts | Fair Value, Measurements, Recurring | FTRs | Level 3 | Low
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		(32)
Commodity contracts | Fair Value, Measurements, Recurring | FTRs | Level 3 | Low | Auction Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh	(58)
Commodity contracts | Fair Value, Measurements, Recurring | FTRs | Level 3 | High
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		610
Commodity contracts | Fair Value, Measurements, Recurring | FTRs | Level 3 | High | Auction Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh	252
Commodity contracts | Fair Value, Measurements, Recurring | FTRs | Level 3 | Weighted Average
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh		0
Commodity contracts | Fair Value, Measurements, Recurring | FTRs | Level 3 | Weighted Average | Auction Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWh	0
Interest rate contracts
Assets
Derivative Assets	$ 12
Liabilities
Derivative Liabilities	8
Interest rate contracts | Level 3
Assets
Derivative Assets	0
Liabilities
Derivative Liabilities	$ 0
Interest rate contracts | Level 3 | Low | Collateral Prepayment Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.0200
Interest rate contracts | Level 3 | Low | Credit Loss Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.0600
Interest rate contracts | Level 3 | High | Collateral Prepayment Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.0300
Interest rate contracts | Level 3 | High | Credit Loss Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.6000
Interest rate contracts | Level 3 | Weighted Average | Collateral Prepayment Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.0295
Interest rate contracts | Level 3 | Weighted Average | Credit Loss Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.1257
Interest rate contracts | Consumer Financing Program | Level 3
Assets
Derivative Assets	$ 0
Liabilities
Derivative Liabilities	$ 134
Interest rate contracts | Consumer Financing Program | Level 3 | Low | Collateral Default Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.0043
Interest rate contracts | Consumer Financing Program | Level 3 | High | Collateral Default Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.9330
Interest rate contracts | Consumer Financing Program | Level 3 | Weighted Average | Collateral Default Rates | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative liability	0.0812
Capacity Contracts | Fair Value, Measurements, Recurring | Capacity Contracts | Level 3
Assets
Derivative Assets	$ 21
Liabilities
Derivative Liabilities	$ 33
Capacity Contracts | Fair Value, Measurements, Recurring | Capacity Contracts | Level 3 | Low | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWd	49
Capacity Contracts | Fair Value, Measurements, Recurring | Capacity Contracts | Level 3 | High | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWd	658
Capacity Contracts | Fair Value, Measurements, Recurring | Capacity Contracts | Level 3 | Weighted Average | Forward Market Price
Fair Value Measurement Inputs and Valuation Techniques [Abstract
Derivative asset/ liability measurement input | $ / MWd	285,000,000

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Fair Value of Financial Instruments - Counterparty Credit Risk (Details) $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($)
Derivative Fair Value Meaurements and Concentration of Credit Risk
Counterparty credit exposure, excluding credit risk exposure under certain long term agreements	$ 1,600
Counterparty credit exposure, collateral held (cash and letters of credit) against positions	426
Counterparty credit exposure, net	$ 1,200
Company's exposure before collateral expected to roll off (as a percent)	63.00%
Net exposure (as a percent)	100.00%
Counterparty credit risk exposure to certain counterparties, threshold (as a percent)	10.00%
Estimated counterparty credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations and solar power purchase agreements for the next 5 years	$ 882
Period of estimated counterparty credit risk exposure under certain long term agreements, including California tolling agreements, South Central load obligations and solar power purchase agreements (in years)	5 years
Investment grade
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	44.00%
Non-Investment grade/Non-Rated
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	56.00%
Utilities, energy merchants, marketers and other
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	80.00%
Financial Institutions
Derivative Fair Value Meaurements and Concentration of Credit Risk
Net exposure (as a percent)	20.00%

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Fair Value of Financial Instruments - Retail Customer Credit Risk (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Derivative Fair Value Meaurements and Concentration of Credit Risk
Provision for credit losses (income recognized) due to loss mitigation efforts	$ 251	$ 11	$ 698
Winter Storm Uri
Derivative Fair Value Meaurements and Concentration of Credit Risk
Provision for credit losses (income recognized) due to loss mitigation efforts		$ (126)	$ 596

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Accounting for Derivative Instruments and Hedging Activities - Narrative (Details) $ in Billions	Mar. 31, 2023 USD ($)
Interest Rate Swap | Term Loan Facility
Derivative [Line Items]
Interest rate hedge	$ 1.0

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Accounting for Derivative Instruments and Hedging Activities - Net Notional Volume Buy/Sell of Open Derivative Transactions (Details) certificate in Millions, bbl in Millions, T in Millions, MWh in Millions, MMBTU in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($) MWh MMBTU certificate T bbl	Dec. 31, 2022 USD ($) MWh MMBTU certificate T bbl
Long | Emissions
Derivative [Line Items]
Derivative, nonmonetary notional amount, mass (ton) | T	0	1
Long | Renewables Energy Certificates
Derivative [Line Items]
Derivative, non-monetary notional amount (in shares) | certificate	12	15
Long | Coal
Derivative [Line Items]
Derivative, nonmonetary notional amount, mass (ton) | T	9	11
Long | Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume (in barrels) | bbl	0	1
Long | Power
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure in (millions of btu) and (megawatt hours) | MWh	201	192
Long | Interest
Derivative [Line Items]
Derivative, notional amount (usd) | $	$ 1,000	$ 0
Long | Foreign Exchange
Derivative [Line Items]
Derivative, notional amount (usd) | $	$ 548	$ 569
Short | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure in (millions of btu) and (megawatt hours) | MMBTU	838	422
Short | Consumer Financing Program
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure in (millions of btu) and (megawatt hours) | MWh	1,116	0

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Accounting for Derivative Instruments and Hedging Activities - Fair Value Within the Derivative Instrument Valuation (Details) - Not Designated as Hedging Instrument - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Derivative [Line Items]
Derivative Assets	$ 6,155	$ 11,994
Derivative Liabilities	5,507	8,441
Interest rate contracts - current
Derivative [Line Items]
Derivative Assets	12	0
Derivative Liabilities	0	0
Interest rate contracts long-term
Derivative [Line Items]
Derivative Assets	0	0
Derivative Liabilities	8	0
Foreign exchange contracts - current
Derivative [Line Items]
Derivative Assets	3	11
Derivative Liabilities	4	1
Foreign exchange contracts - long-term
Derivative [Line Items]
Derivative Assets	2	7
Derivative Liabilities	5	1
Commodity contracts- current
Derivative [Line Items]
Derivative Assets	3,847	7,875
Derivative Liabilities	3,922	6,194
Commodity contracts- long-term
Derivative [Line Items]
Derivative Assets	2,291	4,101
Derivative Liabilities	1,434	2,245
Consumer Financing Program - current
Derivative [Line Items]
Derivative Assets	0	0
Derivative Liabilities	93	0
Consumer Financing Program - long-term
Derivative [Line Items]
Derivative Assets	0	0
Derivative Liabilities	$ 41	$ 0

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Accounting for Derivative Instruments and Hedging Activities - Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Gross Amounts of Recognized Assets / Liabilities	$ 648	$ 3,553
Derivative Instruments	0	0
Cash Collateral (Held) / Posted	71	(1,639)
Net Amount	719	1,914
Interest rate contracts
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Derivative Assets	12
Derivative Instruments	(8)
Cash Collateral (Held)/Posted	0
Net Amount	4
Derivative liabilities	(8)
Derivative Instruments	8
Cash Collateral (Held)/Posted	0
Net Amount	0
Gross Amounts of Recognized Assets / Liabilities	4
Derivative Instruments	0
Cash Collateral (Held) / Posted	0
Net Amount	4
Foreign exchange contract
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Derivative Assets	5	18
Derivative Instruments	(5)	(2)
Cash Collateral (Held)/Posted	0	0
Net Amount	0	16
Derivative liabilities	(9)	(2)
Derivative Instruments	5	2
Cash Collateral (Held)/Posted	0	0
Net Amount	(4)	0
Gross Amounts of Recognized Assets / Liabilities	(4)	16
Derivative Instruments	0	0
Cash Collateral (Held) / Posted	0	0
Net Amount	(4)	16
Commodity contracts
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Derivative Assets	6,138	11,976
Derivative Instruments	(4,926)	(7,897)
Cash Collateral (Held)/Posted	(74)	(1,659)
Net Amount	1,138	2,420
Derivative liabilities	(5,356)	(8,439)
Derivative Instruments	4,926	7,897
Cash Collateral (Held)/Posted	145	20
Net Amount	(285)	(522)
Gross Amounts of Recognized Assets / Liabilities	782	3,537
Derivative Instruments	0	0
Cash Collateral (Held) / Posted	71	(1,639)
Net Amount	853	$ 1,898
Consumer Financing Program
Offsetting of Derivatives by Counterparty Master Agreement Level and Collateral Received or Paid
Derivative liabilities	(134)
Derivative Instruments	0
Cash Collateral (Held)/Posted	0
Net Amount	$ (134)

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Accounting for Derivative Instruments and Hedging Activities - Pre-tax Effects of Economic Hedges not Designated as Cash Flow Hedges (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Unrealized Mark To Market Results [Abstract]
Reversal of previously recognized unrealized (gains) on settled positions related to economic hedges	$ (1,734)	$ (1,232)	$ (41)
Reversal of acquired loss positions related to economic hedges	20	2	256
Total unrealized mark-to-market (losses)/gains for economic hedging activities	(2,863)	1,248	2,716
Reversal of previously recognized unrealized losses/(gains) on settled positions related to trading activity	13	13	(18)
Reversal of acquired (gain) positions related to trading activity	0	0	(1)
Net unrealized gains/(losses) on open positions related to trading activity	25	(17)	(13)
Total unrealized mark-to-market gains/(losses) for trading activity	38	(4)	(32)
Total unrealized (losses)/gains - commodities and foreign exchange	(2,825)	1,244	2,684
Credit Risk Related Contingent Features [Abstract]
Net unrealized (losses)/gains on open positions related to economic hedges	1,100
Collateral required contracts with credit rating contingent features in a net liability position	80
Additional collateral required	8
Adequate Assurance Clauses
Credit Risk Related Contingent Features [Abstract]
Collateral required for contracts in net liability positions that have adequate assurance clauses	600
Not Designated as Hedging Instrument, Economic Hedge
Unrealized Mark To Market Results [Abstract]
Net unrealized (losses)/gains on open positions related to economic hedges	(1,149)	2,478	2,501
Credit Risk Related Contingent Features [Abstract]
Net unrealized (losses)/gains on open positions related to economic hedges		2,500	2,500
Interest rate contracts
Unrealized Mark To Market Results [Abstract]
Total impact to statement of operations	4	0	0
Commodity contracts | Operating revenue
Unrealized Mark To Market Results [Abstract]
Total unrealized (losses)/gains - commodities and foreign exchange	182	(87)	(196)
Commodity contracts | Cost of operations
Unrealized Mark To Market Results [Abstract]
Total unrealized (losses)/gains - commodities and foreign exchange	(2,988)	1,315	2,880
Foreign exchange contract | Cost of operations
Unrealized Mark To Market Results [Abstract]
Total unrealized (losses)/gains - commodities and foreign exchange	(19)	16	0
Commodity and Foreign Exchange Contracts
Unrealized Mark To Market Results [Abstract]
Total unrealized (losses)/gains - commodities and foreign exchange	(2,825)	1,244	2,684
Consumer Financing Program
Unrealized Mark To Market Results [Abstract]
Total impact to statement of operations	$ (16)	$ 0	$ 0

XML

Nuclear Decommissioning Trust Fund - Summary of Aggregate Fair Values and Realized Gains and Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2023	Nov. 01, 2023
Nuclear decommissioning trust fund disclosure
Fair Value	$ 838	$ 0
Unrealized Gains	346
Unrealized Losses	36
Cash and cash equivalents
Nuclear decommissioning trust fund disclosure
Fair Value	15
Unrealized Gains	0
Unrealized Losses	0
U.S. government and federal agency obligations
Nuclear decommissioning trust fund disclosure
Fair Value	86
Unrealized Gains	0
Unrealized Losses	$ 5
Weighted- average maturities (in years)	11 years
Federal agency mortgage-backed securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 101
Unrealized Gains	0
Unrealized Losses	$ 11
Weighted- average maturities (in years)	26 years
Commercial mortgage-backed securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 35
Unrealized Gains	0
Unrealized Losses	$ 4
Weighted- average maturities (in years)	30 years
Corporate debt securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 114
Unrealized Gains	0
Unrealized Losses	$ 13
Weighted- average maturities (in years)	12 years
Equity securities
Nuclear decommissioning trust fund disclosure
Fair Value	$ 486
Unrealized Gains	346
Unrealized Losses	3
Foreign government fixed income securities
Nuclear decommissioning trust fund disclosure
Fair Value	1
Unrealized Gains	0
Unrealized Losses	$ 0
Weighted- average maturities (in years)	17 years
South Texas Project
Nuclear decommissioning trust fund disclosure
Ownership Interest (as a percent)			44.00%

XML

Nuclear Decommissioning Trust Fund - Summary of Proceeds from Sale of Available-for-sale Securities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Regulated Operations [Abstract]
Realized gains	$ 11	$ 14	$ 47
Realized losses	(19)	(25)	(9)
Proceeds from sale of securities	$ 355	$ 448	$ 710

XML

Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Inventory Disclosure [Abstract]
Fuel oil	$ 8	$ 8
Coal	178	114
Natural gas	189	385
Spare parts	68	136
Finished goods	164	108
Total Inventory	$ 607	$ 751

XML

Property, Plant and Equipment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment
Total property, plant, and equipment	$ 3,058	$ 3,170
Accumulated depreciation	(1,295)	(1,478)
Net property, plant, and equipment	1,763	1,692
Depreciation	257	291	$ 384
Facilities and equipment
Property, Plant and Equipment
Total property, plant, and equipment	$ 1,918	1,727
Facilities and equipment | Minimum
Property, Plant and Equipment
Depreciable lives (in years)	1 year
Facilities and equipment | Maximum
Property, Plant and Equipment
Depreciable lives (in years)	40 years
Land and improvements
Property, Plant and Equipment
Total property, plant, and equipment	$ 256	263
Nuclear fuel
Property, Plant and Equipment
Total property, plant, and equipment	$ 0	271
Depreciable lives (in years)	5 years
Hardware and office equipment and furnishings
Property, Plant and Equipment
Total property, plant, and equipment	$ 732	712
Hardware and office equipment and furnishings | Minimum
Property, Plant and Equipment
Depreciable lives (in years)	2 years
Hardware and office equipment and furnishings | Maximum
Property, Plant and Equipment
Depreciable lives (in years)	10 years
Construction in progress
Property, Plant and Equipment
Total property, plant, and equipment	$ 152	$ 197

XML

Leases - Lease Cost and Other Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Lease, Cost [Abstract]
Finance lease cost	$ 8	$ 4	$ 4
Amortization of right-of-use assets	7	4	4
Interest on lease liabilities	1	0	0
Operating lease cost	93	85	91
Short-term lease cost	42	7	3
Variable lease cost	91	86	9
Sublease income	(2)	(2)	(2)
Total lease cost	232	180	105
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	195	183	102
Financing cash flows from finance leases	7	5	6
Right-of-use assets obtained in exchange for new finance lease liabilities	17	3	16
Right-of-use assets obtained in exchange for new operating lease liabilities	$ 52	$ 28	$ 47
Finance leases:
Weighted average remaining lease term (in years)	2 years 10 months 24 days	2 years 7 months 6 days
Weighted average discount rate	4.87%	2.82%
Operating Leases [Abstract]
Weighted average remaining lease term (in years)	3 years 7 months 6 days	4 years 3 months 18 days
Weighted average discount rate	6.00%	5.37%

XML

Leases - Annual Payments Based on the Maturities of Leases (Details) $ in Millions	Dec. 31, 2023 USD ($)
Leases [Abstract]
2024	$ 118
2025	86
2026	34
2027	24
2028	17
Thereafter	32
Total undiscounted lease payments	311
Less present value adjustment	(93)
Operating lease liability	$ 218

XML

Asset Impairments (Details) - USD ($) $ in Millions	3 Months Ended					12 Months Ended
	Dec. 31, 2023	Sep. 30, 2022	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Asset Impairments
Impairment losses on investments						$ 102	$ 0	$ 0
Impairment losses						$ 26	206	$ 544
Goodwill impairment losses			$ 130				130
Gladstone
Asset Impairments
Impairment losses on investments	$ 102
East
Asset Impairments
Impairment losses	4	$ 43	$ 20	$ 16			13
Goodwill impairment losses							130
East | Joliet facility
Asset Impairments
Impairment losses				213
East | PJM Coal Generating Assets
Asset Impairments
Impairment losses					$ 271
Goodwill impairment losses					$ 35
West/Services/Other
Asset Impairments
Impairment losses	20			$ 9
Texas
Asset Impairments
Impairment losses	$ 2
Goodwill impairment losses							$ 0

XML

Goodwill and Other Intangibles - Changes in Goodwill (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2023	Dec. 31, 2022
Goodwill [Roll Forward]
Goodwill, Beginning Balance		$ 1,650	$ 1,795
Goodwill resulted from the acquisition of Vivint		3,494
Impairment losses	$ (130)		(130)
Asset sales		(69)	(6)
Foreign currency translation		4	(9)
Goodwill, Ending Balance		5,079	1,650
Texas
Goodwill [Roll Forward]
Goodwill, Beginning Balance		710	716
Goodwill resulted from the acquisition of Vivint		0
Impairment losses			0
Asset sales		(67)	(6)
Foreign currency translation		0	0
Goodwill, Ending Balance		643	710
East
Goodwill [Roll Forward]
Goodwill, Beginning Balance		723	853
Goodwill resulted from the acquisition of Vivint		0
Impairment losses			(130)
Asset sales		(2)	0
Foreign currency translation		0	0
Goodwill, Ending Balance		721	723
West/Services/Other
Goodwill [Roll Forward]
Goodwill, Beginning Balance		217	226
Goodwill resulted from the acquisition of Vivint		0
Impairment losses			0
Asset sales		0	0
Foreign currency translation		4	(9)
Goodwill, Ending Balance		221	217
Vivint Smart Home
Goodwill [Roll Forward]
Goodwill, Beginning Balance		0	0
Goodwill resulted from the acquisition of Vivint		3,494
Goodwill, Ending Balance		$ 3,494	$ 0

XML

Goodwill and Other Intangibles - Components of Intangible Assets Subject to Amortization (Details) - USD ($) $ in Millions		12 Months Ended
	Mar. 10, 2023	Dec. 31, 2023	Dec. 31, 2022
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		$ 4,244	$ 4,147
Purchases		475	430
Acquisition of businesses		2,803	55
Usage/Sales/Retirements		(474)	(374)
Write-off of fully amortized balances		(72)	(14)
Other		4	0
Balance at end of period		6,921	4,244
Less accumulated amortization		(2,994)	(2,112)
Net carrying amount		3,927	2,132
STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		(59)
Vivint
Finite-lived Intangible Assets [Roll Forward]
Weighted average useful life, years	10 years
Renewables Energy Certificates
Finite-lived Intangible Assets [Roll Forward]
Carrying value		177	186
Emission Allowances
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		624	634
Purchases		10	26
Acquisition of businesses		0	0
Usage/Sales/Retirements		0	(33)
Write-off of fully amortized balances		(1)	(14)
Other		(5)	11
Balance at end of period		628	624
Less accumulated amortization		(533)	(528)
Net carrying amount		95	96
Emission Allowances | STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		0
Customer and Supply Contracts
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		635	638
Purchases		0	0
Acquisition of businesses		0	0
Usage/Sales/Retirements		0	0
Write-off of fully amortized balances		(28)	0
Other		2	(3)
Balance at end of period		609	635
Less accumulated amortization		(328)	(235)
Net carrying amount		281	400
Customer and Supply Contracts | STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		0
Customer Relationships
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		1,730	1,679
Purchases		0	0
Acquisition of businesses		1,773	55
Usage/Sales/Retirements		0	0
Write-off of fully amortized balances		(43)	0
Other		4	(4)
Balance at end of period		3,464	1,730
Less accumulated amortization		(1,300)	(787)
Net carrying amount		2,164	$ 943
Weighted average useful life, years			6 years
Customer Relationships | STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		0
Customer Relationships | Vivint
Finite-lived Intangible Assets [Roll Forward]
Weighted average useful life, years	12 years
Marketing Partnerships
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		284	$ 284
Purchases		0	0
Acquisition of businesses		10	0
Usage/Sales/Retirements		0	0
Write-off of fully amortized balances		0	0
Other		1	0
Balance at end of period		295	284
Less accumulated amortization		(170)	(146)
Net carrying amount		125	138
Marketing Partnerships | STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		0
Technology
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		0
Purchases		0
Acquisition of businesses		860
Usage/Sales/Retirements		0
Write-off of fully amortized balances		0
Other		0
Balance at end of period		860	0
Less accumulated amortization		(230)
Net carrying amount		630
Technology | STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		0
Technology | Vivint
Finite-lived Intangible Assets [Roll Forward]
Weighted average useful life, years	5 years
Trade Names
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		679	683
Purchases		0	0
Acquisition of businesses		160	0
Usage/Sales/Retirements		0	0
Write-off of fully amortized balances		0	0
Other		2	(4)
Balance at end of period		841	679
Less accumulated amortization		(401)	(341)
Net carrying amount		440	338
Trade Names | STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		0
Trade Names | Vivint
Finite-lived Intangible Assets [Roll Forward]
Weighted average useful life, years	10 years
Other
Finite-lived Intangible Assets [Roll Forward]
Balance at beginning of period		292	229
Purchases		465	404
Acquisition of businesses		0	0
Usage/Sales/Retirements		(474)	(341)
Write-off of fully amortized balances		0	0
Other		0	0
Balance at end of period		224	292
Less accumulated amortization		(32)	(75)
Net carrying amount		192	$ 217
Other | STP | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Finite-lived Intangible Assets [Roll Forward]
Sale of STP		(59)
Net carrying amount		$ 47

XML

Goodwill and Other Intangibles - Schedule of Amortization and Retirement of Intangible Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Finite-Lived Intangible Assets [Line Items]
Total amortization	$ 1,001	$ 490	$ 495
Depreciation and amortization	1,127	634	785
Emission Allowances
Finite-Lived Intangible Assets [Line Items]
Total amortization	6	6	24
Customer and Supply Contracts
Finite-Lived Intangible Assets [Line Items]
Total amortization	121	141	66
Customer Relationships
Finite-Lived Intangible Assets [Line Items]
Total amortization	556	269	327
Marketing Partnerships
Finite-Lived Intangible Assets [Line Items]
Total amortization	24	23	24
Technology
Finite-Lived Intangible Assets [Line Items]
Total amortization	230	0	0
Trade Names
Finite-Lived Intangible Assets [Line Items]
Total amortization	60	47	47
Other
Finite-Lived Intangible Assets [Line Items]
Total amortization	$ 4	4	7
Depreciation and amortization		$ 4	$ 3

XML

Goodwill and Other Intangibles - Schedule of Estimated Amortization of Intangible Asset for the Next Five Years (Details) $ in Millions	Dec. 31, 2023 USD ($)
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	$ 876
2025	684
2026	556
2027	425
2028	276
Emission Allowances
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	17
2025	14
2026	9
2027	8
2028	9
Customer and Supply Contracts
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	73
2025	50
2026	52
2027	30
2028	13
Customer Relationships
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	478
2025	371
2026	300
2027	233
2028	189
Marketing Partnerships
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	24
2025	23
2026	23
2027	23
2028	15
Technology
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	227
2025	176
2026	130
2027	89
2028	9
Trade Names
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	54
2025	47
2026	39
2027	39
2028	39
Other
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2024	3
2025	3
2026	3
2027	3
2028	$ 2

XML

Goodwill and Other Intangibles - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Held-for-sale
Goodwill and Other Intangibles
Emission allowances held-for-sale	$ 4	$ 8

XML

Long-term Debt and Finance Leases - Schedule of Long-term Debt and Finance Leases (Details) $ / shares in Units, $ in Millions		12 Months Ended
	Jan. 31, 2024 $ / shares	Dec. 31, 2023 USD ($) $ / shares	Dec. 31, 2022 USD ($) $ / shares	Aug. 23, 2021	Dec. 02, 2020	May 24, 2019	Dec. 07, 2017	Aug. 02, 2016
Debt Instrument [Line Items]
Long-term debt		$ 10,940	$ 8,100
Finance leases		$ 19	$ 11
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]		Total long-term debt and finance leases	Total long-term debt and finance leases
Total long-term debt and finance lease obligations		$ 10,959	$ 8,111
Less current maturities		(620)	(63)
Less debt issuance costs		(60)	(70)
Discounts		(146)	(2)
Total long-term debt and finance leases		10,133	7,976
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		$ (146)	(2)
Senior Notes, due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage		6.625%
Tax-exempt bonds
Debt Instrument [Line Items]
Long-term debt		$ 466	466
Recourse Debt
Debt Instrument [Line Items]
Long-term debt		8,220	8,100
Recourse Debt | Senior Notes, due 2027
Debt Instrument [Line Items]
Long-term debt		$ 375	375
Interest rate, stated percentage		6.625%						6.625%
Recourse Debt | Senior Notes, due 2028
Debt Instrument [Line Items]
Long-term debt		$ 821	821
Interest rate, stated percentage		5.75%					5.75%
Recourse Debt | Senior Notes, due 2029
Debt Instrument [Line Items]
Long-term debt		$ 733	733
Interest rate, stated percentage		5.25%				5.25%
Recourse Debt | Senior Notes, due 2029
Debt Instrument [Line Items]
Long-term debt		$ 500	500
Interest rate, stated percentage		3.375%			3.375%
Recourse Debt | Senior Notes, due 2031
Debt Instrument [Line Items]
Long-term debt		$ 1,030	1,030
Interest rate, stated percentage		3.625%
Recourse Debt | Senior Notes, due 2032
Debt Instrument [Line Items]
Long-term debt		$ 480	1,100
Interest rate, stated percentage		3.875%		3.875%
Recourse Debt | Convertible Senior Notes Due 2048
Debt Instrument [Line Items]
Long-term debt		$ 575	575
Discounts		$ (12)	$ 0
Interest rate, stated percentage		2.75%
Conversion price per common share (in usd per share) | $ / shares		$ 41.83	$ 43.46
Conversion ratio		0.0239079	0.0230116
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		$ (12)	$ 0
Recourse Debt | Convertible Senior Notes Due 2048 | Subsequent Event
Debt Instrument [Line Items]
Conversion price per common share (in usd per share) | $ / shares	$ 41.53
Conversion ratio	0.0240763
Recourse Debt | Senior Secured First Lien Notes, due 2024
Debt Instrument [Line Items]
Long-term debt		$ 600	600
Interest rate, stated percentage		3.75%
Recourse Debt | Senior Secured First Lien Notes, due 2025
Debt Instrument [Line Items]
Long-term debt		$ 500	500
Interest rate, stated percentage		2.00%
Recourse Debt | Senior Secured First Lien Notes, due 2027
Debt Instrument [Line Items]
Long-term debt		$ 900	900
Interest rate, stated percentage		2.45%
Recourse Debt | Senior Secured First Lien Notes, due 2029
Debt Instrument [Line Items]
Long-term debt		$ 500	500
Interest rate, stated percentage		4.45%
Recourse Debt | Senior Secured First Lien Notes, due 2033
Debt Instrument [Line Items]
Long-term debt		$ 740	0
Interest rate, stated percentage		7.00%
Recourse Debt | Tax-exempt bonds
Debt Instrument [Line Items]
Long-term debt		$ 466	466
Recourse Debt | Tax-exempt bonds | Minimum
Debt Instrument [Line Items]
Interest rate, stated percentage		1.25%
Recourse Debt | Tax-exempt bonds | Maximum
Debt Instrument [Line Items]
Interest rate, stated percentage		4.75%
Recourse Debt | Senior Secured First Lien Notes, due 2024, 2025, 2027, 2029 and 2033
Debt Instrument [Line Items]
Discounts		$ (10)	(2)
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		(10)	(2)
Non Recourse Debt
Debt Instrument [Line Items]
Long-term debt		2,720	0
Non Recourse Debt | Vivint 5.750% Senior Secured Notes due 2029
Debt Instrument [Line Items]
Long-term debt		800	0
Discounts		$ (103)	0
Interest rate, stated percentage		5.75%
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		$ (103)	0
Non Recourse Debt | Vivint 6.750% Senior Secured Notes due 2027
Debt Instrument [Line Items]
Long-term debt		$ 600	0
Interest rate, stated percentage		6.75%
Non Recourse Debt | Vivint Senior Secured Notes due 2028
Debt Instrument [Line Items]
Long-term debt		$ 1,320	0
Discounts		(21)	0
Debt Instrument, Unamortized Discount [Abstract]
Total discounts		$ (21)	$ 0
Non Recourse Debt | Vivint Senior Secured Notes due 2028 | SOFR
Debt Instrument [Line Items]
Interest rate, stated percentage		3.51%

XML

Long-term Debt and Finance Leases - Annual Payments Based on the Maturities of Debt and Capital Leases (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Debt Disclosure [Abstract]
2024	$ 620
2025	769
2026	16
2027	1,890
2028	2,145
Thereafter	5,519
Total long-term debt and finance lease obligations	$ 10,959	$ 8,111

XML

Long-term Debt and Finance Leases - Revolving Credit Facility (Details) - Revolving Credit Facility Agreement - USD ($) $ in Millions	Mar. 13, 2023	Feb. 14, 2023	Dec. 31, 2023
Revolving Credit Facility
Line of Credit Facility [Line Items]
Increase in existing borrowing commitments	$ 45	$ 600
Revolving credit facility		$ 4,305
Collateral exclusion for percentage of equity interests that exceeds total outstanding voting equity interests of certain foreign subsidiaries		66.00%
Collateral excluded, subsidiaries and other assets aggregate fair value, maximum		$ 750
Borrowings outstanding			$ 0
Letter of Credit
Line of Credit Facility [Line Items]
Letter of credit			$ 883

XML

Long-term Debt and Finance Leases - Senior Notes Issuance and Redemptions (Details) - USD ($)	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Mar. 09, 2023
Debt Instrument [Line Items]
Principal repurchased			$ 1,855,000,000
Repayment of senior notes			1,949,000,000
Gain/(Loss) on debt extinguishment	$ 109,000,000	$ 0	(77,000,000)
Senior Notes
Debt Instrument [Line Items]
Write off of deferred debt issuance cost			12,000,000
Senior Secured First Lien Notes, due 2033 | Senior Notes
Debt Instrument [Line Items]
Aggregate principal amount				$ 740,000,000
Interest rate, stated percentage				7.00%
Senior Notes, due 2032 | Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage	3.875%
Principal repurchased	$ 620,000,000
Repayment of senior notes	509,000,000
Payment of accrued interest	$ 7,000,000
Average early redemption percentage	81.00%
Gain/(Loss) on debt extinguishment	$ 109,000,000
Write off of deferred debt issuance cost	$ 9,000,000
Senior Notes | Senior Notes
Debt Instrument [Line Items]
Principal repurchased			1,900,000,000
Repayment of senior notes			1,900,000,000
Gain/(Loss) on debt extinguishment			$ 77,000,000

XML

Long-term Debt and Finance Leases - Senior Notes Redemptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023
Debt Instrument [Line Items]
Principal Repurchased	$ 1,855
Cash Paid	1,949
Accrued interest	29
Senior Notes due 2026
Debt Instrument [Line Items]
Interest rate, stated percentage		7.25%
Principal Repurchased	1,000
Cash Paid	$ 1,056
Average Early Redemption Percentage	103.625%
Senior Notes, due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage		6.625%
Principal Repurchased	$ 855
Cash Paid	$ 893
Average Early Redemption Percentage	103.313%

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Long-term Debt and Finance Leases - Issuance of Convertible Senior Notes (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($) tradingDay $ / shares	Dec. 31, 2022 USD ($) $ / shares	Jan. 01, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2018
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance	$ 2,906	$ 3,828		$ 3,600	$ 1,680
Deferred tax liabilities	(1,190)	(1,270)
Additional Paid-In Capital
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance	3,416	8,457		8,531	8,517
Retained Earnings
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance	$ 820	$ 1,408		464	$ (1,403)
Cumulative Effect, Period of Adoption, Adjustment
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance				(43)
Debt discount			$ 57
Deferred tax liabilities			14
Cumulative Effect, Period of Adoption, Adjustment | Additional Paid-In Capital
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance			(100)	(100)
Cumulative Effect, Period of Adoption, Adjustment | Retained Earnings
Debt Instrument [Line Items]
Adjustment for adoption of new accounting guidance			$ 57	$ 57
Convertible Senior Notes Due 2048
Debt Instrument [Line Items]
Debt discount amortization period						7 years
Convertible Senior Notes Due 2048 | Recourse Debt
Debt Instrument [Line Items]
Conversion price per common share (in usd per share) | $ / shares	$ 41.83	$ 43.46
Conversion ratio	0.0239079	0.0230116
Carrying amount of equity component	$ 572	$ 570
Debt, convertible, percentage of stock price trigger	130.00%
Debt convertible, threshold trading days | tradingDay	20
Debt convertible, threshold consecutive trading days | tradingDay	30

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Long-term Debt and Finance Leases - Interest Expense in Connection with Convertible Senior Notes, due 2048 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Amortization of discount and deferred finance costs	$ 52	$ 23	$ 39
Convertible Senior Notes Due 2048 | Recourse Debt
Debt Instrument [Line Items]
Contractual interest expense	16	16	16
Amortization of discount and deferred finance costs	2	1	15
Total	$ 18	$ 17	$ 31
Effective Interest Rate	3.18%	3.01%	5.34%

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Long-term Debt and Finance Leases - Senior Notes Outstanding with Early Redemption Features (Details)	12 Months Ended
	Dec. 31, 2023	Aug. 23, 2021	Dec. 02, 2020	May 24, 2019	Dec. 07, 2017	Aug. 02, 2016
6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%
Recourse Debt | 6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%					6.625%
Recourse Debt | 5.750% Senior Notes due 2028
Debt Instrument [Line Items]
Interest rate, stated percentage	5.75%				5.75%
Recourse Debt | 5.250% Senior Notes due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	5.25%			5.25%
Recourse Debt | 3.375% Senior Notes due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	3.375%		3.375%
Recourse Debt | Senior Notes due 2031
Debt Instrument [Line Items]
Interest rate, stated percentage			3.625%
Recourse Debt | Senior Notes, due 2032
Debt Instrument [Line Items]
Interest rate, stated percentage	3.875%	3.875%
Recourse Debt | Senior Notes | Low
Debt Instrument [Line Items]
Redemption percentage of principal	25.00%
Recourse Debt | Senior Notes | Maximum
Debt Instrument [Line Items]
Redemption percentage of principal	30.00%

XML

Long-term Debt and Finance Leases - Senior Notes Redemption Period (Details)	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2021	Aug. 23, 2021	Dec. 02, 2020	May 24, 2019	Dec. 07, 2017	Aug. 02, 2016
6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Redemption Percentage		103.313%
Interest rate, stated percentage	6.625%
Senior Notes, due 2032 | Redemption Period Prior to August 15 2024
Debt Instrument [Line Items]
Redemption Percentage	103.875%
Outstanding principal after redemption, percentage (at least)	50.00%
Senior Notes, due 2032 | Redemption Period Prior to February 15 2027
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Senior Notes, due 2032 | 2027
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	101.938%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	102.188%
Senior Notes, due 2032 | 2028
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	101.292%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	101.458%
Senior Notes, due 2032 | 2029
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	100.646%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	100.729%
Senior Notes, due 2032 | 2030 and thereafter
Debt Instrument [Line Items]
Redemption Percentage (If Sustainability Performance Target has been satisfied and confirmed by External Verifier)	100.00%
Redemption Percentage (If Sustainability Performance Target has not been satisfied and/or confirmed by External Verifier)	100.00%
Recourse Debt | 6.625% Senior Notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.625%						6.625%
Recourse Debt | 6.625% Senior Notes due 2027 | July 15, 2023 to July 14, 2024
Debt Instrument [Line Items]
Redemption Percentage	101.104%
Recourse Debt | 6.625% Senior Notes due 2027 | July 15, 2024 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt | 5.750% Senior Notes due 2028
Debt Instrument [Line Items]
Interest rate, stated percentage	5.75%					5.75%
Recourse Debt | 5.750% Senior Notes due 2028 | January 15, 2024 to January 14, 2025
Debt Instrument [Line Items]
Redemption Percentage	101.917%
Recourse Debt | 5.750% Senior Notes due 2028 | January 15, 2025 to January 14, 2026
Debt Instrument [Line Items]
Redemption Percentage	100.958%
Recourse Debt | 5.750% Senior Notes due 2028 | January 15, 2026 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt | 5.250% Senior Notes due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	5.25%				5.25%
Recourse Debt | 5.250% Senior Notes due 2029 | Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%
Recourse Debt | 5.250% Senior Notes due 2029 | Redemption Period Prior to June 15, 2024
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Present value of note (as percentage)	1.02625
Recourse Debt | 5.250% Senior Notes due 2029 | June 15, 2024 to June 14, 2025
Debt Instrument [Line Items]
Redemption Percentage	102.625%
Recourse Debt | 5.250% Senior Notes due 2029 | June 15, 2025 to June 14, 2026
Debt Instrument [Line Items]
Redemption Percentage	101.75%
Recourse Debt | 5.250% Senior Notes due 2029 | June 15, 2026 to June 14, 2027
Debt Instrument [Line Items]
Redemption Percentage	100.875%
Recourse Debt | 5.250% Senior Notes due 2029 | June 15, 2027 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt | 3.375% Senior Notes Due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	3.375%			3.375%
Recourse Debt | 3.375% Senior Notes Due 2029 | February 15, 2024 to February 14, 2025
Debt Instrument [Line Items]
Redemption Percentage	101.688%
Recourse Debt | 3.375% Senior Notes Due 2029 | February 15, 2025 to February 14, 2026
Debt Instrument [Line Items]
Redemption Percentage	100.844%
Recourse Debt | 3.375% Senior Notes Due 2029 | February 15, 2026 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt | Senior Notes due 2031
Debt Instrument [Line Items]
Interest rate, stated percentage				3.625%
Recourse Debt | Senior Notes due 2031 | Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%
Recourse Debt | Senior Notes due 2031 | Redemption Period Prior to February 15, 2026
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Present value of note (as percentage)	1.01813
Recourse Debt | Senior Notes due 2031 | February 15, 2026 to February 14, 2027
Debt Instrument [Line Items]
Redemption Percentage	101.813%
Recourse Debt | Senior Notes due 2031 | February 15, 2027 to February 14, 2028
Debt Instrument [Line Items]
Redemption Percentage	101.208%
Recourse Debt | Senior Notes due 2031 | February 15, 2028 to February 14, 2029
Debt Instrument [Line Items]
Redemption Percentage	100.604%
Recourse Debt | Senior Notes due 2031 | February 15, 2029 and thereafter
Debt Instrument [Line Items]
Redemption Percentage	100.00%
Recourse Debt | Senior Notes, due 2032
Debt Instrument [Line Items]
Redemption Percentage	40.00%
Interest rate, stated percentage	3.875%		3.875%
Recourse Debt | Senior Notes, due 2032 | Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%

XML

Long-term Debt and Finance Leases - Receivables Securitizations and Repurchase Facility (Details) - USD ($)	Oct. 06, 2023	Dec. 31, 2023	Jun. 22, 2023	Jun. 21, 2023	Dec. 31, 2020
Receivables Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Credit facility			$ 1,400,000,000	$ 1,000,000,000
Secured Debt | Receivables Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Weighted average interest rate		0.841%
Borrowings outstanding		$ 0
Secured Debt | Receivables Facility | Letter of Credit
Debt Instrument [Line Items]
Letter of credit		1,000,000,000
Secured Debt | Repurchase Facility
Debt Instrument [Line Items]
Credit facility					$ 150,000,000
Borrowings outstanding		$ 0
Commitment fee	$ 0
Secured Debt | Repurchase Facility | SOFR
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	1.55%

XML

Long-term Debt and Finance Leases - Bilateral Letter of Credit Facilities (Details) - Bilateral Letter of Credit Facilities - USD ($) $ in Millions	Oct. 17, 2023	May 30, 2023	May 19, 2023	Dec. 31, 2023
Secured Debt
Debt Instrument [Line Items]
Increase in existing borrowing commitments	$ 50	$ 100	$ 25
Letter of Credit
Debt Instrument [Line Items]
Revolving credit facility				$ 850
Letter of credit				$ 671

XML

Long-term Debt and Finance Leases - Tax Exempt Bonds (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Long-term debt	$ 10,940	$ 8,100
NRG Indian River Power 2020, tax exempt bonds, due 2040
Debt Instrument [Line Items]
Long-term debt	$ 57	57
Interest rate, stated percentage	1.25%
NRG Indian River Power 2020, tax exempt bonds, due 2045
Debt Instrument [Line Items]
Long-term debt	$ 190	190
Interest rate, stated percentage	1.25%
NRG Dunkirk 2020, tax exempt bonds, due 2042
Debt Instrument [Line Items]
Long-term debt	$ 59	59
Interest rate, stated percentage	4.25%
City of Texas City, tax exempt bonds, due 2045
Debt Instrument [Line Items]
Long-term debt	$ 33	33
Interest rate, stated percentage	4.125%
Fort Bend County, tax exempt bonds, due 2038
Debt Instrument [Line Items]
Long-term debt	$ 54	54
Interest rate, stated percentage	4.75%
Fort Bend County, tax exempt bonds, due 2042
Debt Instrument [Line Items]
Long-term debt	$ 73	73
Interest rate, stated percentage	4.75%
Tax-exempt bonds
Debt Instrument [Line Items]
Long-term debt	$ 466	$ 466

XML

Long-term Debt and Finance Leases - Dunkirk Bonds (Details) - USD ($) $ in Millions	Dec. 31, 2023	Apr. 03, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Long-term debt	$ 10,940		$ 8,100
Dunkirk Bonds
Debt Instrument [Line Items]
Long-term debt		$ 59
Interest rate, stated percentage		4.25%

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Long-term Debt and Finance Leases - Pre-Capitalized Trust Securities Facility (Details) $ in Millions	Aug. 29, 2023 USD ($)
Facility Agreement
Debt Instrument [Line Items]
Trust facility fee on unexercised portion of issuance rights, semi-annual payment, percentage	3.13427%
Failure to pay facility fee, cure period	30 days
Facility Agreement | Senior Secured First Lien Notes due 2028
Debt Instrument [Line Items]
Aggregate principal amount	$ 500
Interest rate, stated percentage	7.467%
LC Agreement | Letter of Credit
Debt Instrument [Line Items]
Credit facility	$ 485
Pre-Capitalized Trust Securities Redeemable July 2028 | Alexander Funding Trust II
Debt Instrument [Line Items]
Sale pre-capitalized trust securities	$ 500

XML

Long-term Debt and Finance Leases - Vivint Smart Home Acquired Debt (Details) - USD ($)	Dec. 31, 2023	Mar. 10, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Borrowings outstanding	$ 10,940,000,000		$ 8,100,000,000
Vivint Credit Agreement | Term Loan Facility
Debt Instrument [Line Items]
Borrowings outstanding	1,300,000,000
Vivint Credit Agreement | Revolving Credit Facility
Debt Instrument [Line Items]
Borrowings outstanding	0
Vivint Credit Agreement | Vivint | Term Loan Facility
Debt Instrument [Line Items]
Revolving credit facility		$ 1,400,000,000
Vivint Credit Agreement | Vivint | Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility		$ 370,000,000
Non Recourse Debt
Debt Instrument [Line Items]
Borrowings outstanding	$ 2,720,000,000		0
Non Recourse Debt | Vivint 6.750% Senior Secured Notes due 2027
Debt Instrument [Line Items]
Interest rate, stated percentage	6.75%
Borrowings outstanding	$ 600,000,000		0
Non Recourse Debt | Vivint 6.750% Senior Secured Notes due 2027 | Vivint
Debt Instrument [Line Items]
Interest rate, stated percentage	6.75%	6.75%
Borrowings outstanding	$ 600,000,000
Non Recourse Debt | Vivint 5.750% Senior Secured Notes due 2029
Debt Instrument [Line Items]
Interest rate, stated percentage	5.75%
Borrowings outstanding	$ 800,000,000		$ 0
Non Recourse Debt | Vivint 5.750% Senior Secured Notes due 2029 | Vivint
Debt Instrument [Line Items]
Interest rate, stated percentage	5.75%	5.75%
Borrowings outstanding	$ 800,000,000

XML

Long-term Debt and Finance Leases - Vivint Senior Notes Redemption Period (Details) - Senior Notes	12 Months Ended
	Dec. 31, 2023
Redemption Period Prior To July 15, 2024
Debt Instrument [Line Items]
Average Early Redemption Percentage	100.00%
Premium percentage of principal amount of note discount factor (as percent)	1.00%
Redemption Period Prior To July 15, 2024 | Treasury Rate
Debt Instrument [Line Items]
Treasury rate redemption (as percentage)	0.50%
July 15, 2024 to July 14, 2025
Debt Instrument [Line Items]
Average Early Redemption Percentage	102.875%
July 15, 2025 to July 14, 2026
Debt Instrument [Line Items]
Average Early Redemption Percentage	101.438%
July 15, 2026 and thereafter
Debt Instrument [Line Items]
Average Early Redemption Percentage	100.10%
Vivint 6.750% Senior Secured Notes due 2027 | February 15, 2024 to February 14, 2025
Debt Instrument [Line Items]
Average Early Redemption Percentage	101.688%
Vivint 6.750% Senior Secured Notes due 2027 | February 15, 2025 and thereafter
Debt Instrument [Line Items]
Average Early Redemption Percentage	100.00%

XML

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Nov. 01, 2023
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of December 31, 2022	$ 758
Revisions in estimates for current obligations	(10)
Additions	13
Spending for current obligations	(42)
Accretion	39
Dispositions	(351)
Balance as of December 31, 2023	$ 407
STP
Asset Retirement Obligations [Line Items]
Ownership percentage	44.00%	44.00%
STP | Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations
Asset Retirement Obligations [Line Items]
Ownership percentage		44.00%
Nuclear Decommission
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of December 31, 2022	$ 340
Revisions in estimates for current obligations	(13)
Additions	0
Spending for current obligations	0
Accretion	16
Dispositions	(343)
Balance as of December 31, 2023	0
Other
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of December 31, 2022	418
Revisions in estimates for current obligations	3
Additions	13
Spending for current obligations	(42)
Accretion	23
Dispositions	(8)
Balance as of December 31, 2023	$ 407

XML

Benefit Plans and Other Postretirement Benefits - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2023 USD ($) benefitPlan	Dec. 31, 2022 USD ($)	Nov. 01, 2023
Benefit Plans and Other Postretirement Benefits
Number of qualified pension plans | benefitPlan	3
STP
Benefit Plans and Other Postretirement Benefits
Ownership percentage	44.00%		44.00%
Pension Benefits
Benefit Plans and Other Postretirement Benefits
Expects to contribute to the pension plans	$ 43
Actuarial gain (loss)	(22)	$ 289
Pension Benefits | GenOn
Benefit Plans and Other Postretirement Benefits
Expects to contribute to the pension plans	$ 23

XML

Benefit Plans and Other Postretirement Benefits - Net Benefit Costs and Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pension Benefits
Annual periodic pension cost
Service cost benefits earned	$ 5	$ 7	$ 9
Interest cost on benefit obligation	50	41	27
Expected return on plan assets	(39)	(47)	(66)
Amortization of unrecognized net loss	6	3	1
Curtailment expense	(1)	14	2
Net periodic benefit cost/(credit)	21	18	(27)
Pension and other post retirement benefit obligations
Benefit obligation at January 1	1,036	1,452
Service cost	5	7	9
Interest cost	50	41	27
Actuarial loss/(gain)	22	(289)
Employee and retiree contributions	0	0
Curtailment and special termination benefit loss	(2)	0
Benefit payments	(89)	(171)
Foreign exchange translation	1	(4)
Benefit obligation at December 31	1,023	1,036	1,452
Fair value of plan assets for pension and other post retirement benefit
Fair value of plan assets at January 1	844	1,336
Actual return on plan assets	93	(317)
Employee and retiree contributions	0	0
Employer contributions	2	0
Benefit payments	(89)	(171)
Foreign exchange translation	1	(4)
Fair value of plan assets at December 31	851	844	1,336
Funded status at December 31 — excess of obligation over assets	(172)	(192)
Other Postretirement Benefits Plan
Annual periodic pension cost
Service cost benefits earned	0	0
Interest cost on benefit obligation	4	2	2
Amortization of unrecognized prior service cost	(8)	(8)	(10)
Amortization of unrecognized net loss	1	2	1
Curtailment expense	0	0	1
Net periodic benefit cost/(credit)	(3)	(4)	(6)
Pension and other post retirement benefit obligations
Benefit obligation at January 1	84	105
Service cost	0	0
Interest cost	4	2	2
Actuarial loss/(gain)	(5)	(11)
Employee and retiree contributions	4	3
Curtailment and special termination benefit loss	(1)	0
Benefit payments	(11)	(15)
Foreign exchange translation	0	0
Benefit obligation at December 31	75	84	105
Fair value of plan assets for pension and other post retirement benefit
Fair value of plan assets at January 1	0	0
Actual return on plan assets	0	0
Employee and retiree contributions	4	3
Employer contributions	7	12
Benefit payments	(11)	(15)
Foreign exchange translation	0	0
Fair value of plan assets at December 31	0	0	$ 0
Funded status at December 31 — excess of obligation over assets	$ (75)	$ (84)

XML

Benefit Plans and Other Postretirement Benefits - Amounts Recognized in the Balance Sheets and OCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pension Benefits
Amounts recognized in balance sheet
Other current liabilities	$ 0	$ 0
Other non-current liabilities	172	192
Amounts recognized in accumulated OCI
Net loss/(gain)	73	110
Prior service cost/(credit)	0	1
Total/Net accumulated OCI	73	111
Other changes in plan assets and benefit obligations recognized in other comprehensive income
Net actuarial (gain)/loss	(31)	74
Amortization of net actuarial loss	(6)	(3)
Amortization of prior service cost	0	0
Effect of settlement/curtailment	(1)	(14)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(38)	57
Net periodic benefit cost/(credit)	21	18	$ (27)
Net recognized in net periodic pension (credit)/cost and OCI	(17)	75
Significant components of NRG's domestic pension plan
Projected benefit obligation	1,023	1,036	1,452
Accumulated benefit obligation	1,015	1,022
Fair value of plan assets	851	844	1,336
Other Postretirement Benefits Plan
Amounts recognized in balance sheet
Other current liabilities	5	7
Other non-current liabilities	70	77
Amounts recognized in accumulated OCI
Net loss/(gain)	(14)	(7)
Prior service cost/(credit)	(4)	(12)
Total/Net accumulated OCI	(18)	(19)
Other changes in plan assets and benefit obligations recognized in other comprehensive income
Net actuarial (gain)/loss	(5)	(11)
Amortization of net actuarial loss	(1)	(2)
Amortization of prior service cost	8	8
Effect of settlement/curtailment	(1)	0
Other changes in plan assets and benefit obligations recognized in other comprehensive income	1	(5)
Net periodic benefit cost/(credit)	(3)	(4)	(6)
Net recognized in net periodic pension (credit)/cost and OCI	(2)	(9)
Significant components of NRG's domestic pension plan
Projected benefit obligation	75	84	105
Fair value of plan assets	$ 0	$ 0	$ 0

XML

Benefit Plans and Other Postretirement Benefits - Fair Values of Pension Assets by Asset Category and Level Within the Fair Value Hierarchy (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Minimum
Significant assumptions used to calculate NRG's benefit expense
Aon Hewitt above median yield curve discount rate (in years)	6 months
Maximum
Significant assumptions used to calculate NRG's benefit expense
Aon Hewitt above median yield curve discount rate (in years)	99 years
Pension Benefits
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	$ 851	$ 844	$ 1,336
Weighted-Average Assumptions
Discount rate	4.97%	5.18%
Interest crediting rate	5.67%	5.21%
Rate of compensation increase	3.06%	3.06%
Significant assumptions used to calculate NRG's benefit expense
Discount rate	5.18%		2.55%
Interest crediting rate	5.21%	3.07%	3.13%
Expected return on plan assets	5.55%	4.99%	5.62%
Rate of compensation increase	3.06%	3.06%	3.06%
Pension Benefits | Minimum
Significant assumptions used to calculate NRG's benefit expense
Discount rate	2.89%
Pension Benefits | Weighted Average
Significant assumptions used to calculate NRG's benefit expense
Discount rate	4.71%
Pension Benefits | Maximum
Significant assumptions used to calculate NRG's benefit expense
Discount rate	5.41%
Pension Benefits | Common/collective trust investment — U.S. equity
Target allocations
Target allocation of pension plan assets (as percent)	19.00%
Pension Benefits | Common/collective trust investment — non-U.S. equity
Target allocations
Target allocation of pension plan assets (as percent)	12.00%
Pension Benefits | Common/collective trust investment — non-core assets
Target allocations
Target allocation of pension plan assets (as percent)	17.00%
Pension Benefits | Common/collective trust investment — fixed income
Target allocations
Target allocation of pension plan assets (as percent)	52.00%
Pension Benefits | Quoted Prices in Active Markets for Identical Assets (Level 1)
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	$ 19	$ 22
Pension Benefits | Quoted Prices in Active Markets for Identical Assets (Level 1) | Common/collective trust investment — U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits | Quoted Prices in Active Markets for Identical Assets (Level 1) | Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits | Quoted Prices in Active Markets for Identical Assets (Level 1) | Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits | Quoted Prices in Active Markets for Identical Assets (Level 1) | Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits | Quoted Prices in Active Markets for Identical Assets (Level 1) | Short-term investment fund
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	19	22
Pension Benefits | Significant Observable Inputs (Level 2)
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	483	491
Pension Benefits | Significant Observable Inputs (Level 2) | Common/collective trust investment — U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	156	155
Pension Benefits | Significant Observable Inputs (Level 2) | Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	58	65
Pension Benefits | Significant Observable Inputs (Level 2) | Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	81	90
Pension Benefits | Significant Observable Inputs (Level 2) | Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	188	181
Pension Benefits | Significant Observable Inputs (Level 2) | Short-term investment fund
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	0	0
Pension Benefits | Total
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	502	513
Pension Benefits | Total | Common/collective trust investment — U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	156	155
Pension Benefits | Total | Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	58	65
Pension Benefits | Total | Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	81	90
Pension Benefits | Total | Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	188	181
Pension Benefits | Total | Short-term investment fund
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	19	22
Pension Benefits | Net Asset Value
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	851	844
Pension Benefits | Net Asset Value | Common/collective trust investment — non-U.S. equity
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	32	33
Pension Benefits | Net Asset Value | Common/collective trust investment — non-core assets
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	47	55
Pension Benefits | Net Asset Value | Common/collective trust investment — fixed income
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	243	220
Pension Benefits | Net Asset Value | Partnerships/joint ventures
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	27	23
Other Postretirement Benefits Plan
Benefit Plans and Other Postretirement Benefits
Fair value of plan assets	$ 0	$ 0	$ 0
Weighted-Average Assumptions
Discount rate	4.96%	5.19%
Interest crediting rate	4.66%	4.00%
Rate of compensation increase	0.00%	0.00%
Health care trend rate	7.70%	7.00%
Health care trend rate	4.50%	4.40%
Year Health care cost trend rate reaches ultimate trend rate	2033	2031
Significant assumptions used to calculate NRG's benefit expense
Discount rate	5.19%	2.82%	2.81%
Interest crediting rate	4.00%	1.94%	1.62%
Expected return on plan assets	0.00%	0.00%	0.00%
Rate of compensation increase	0.00%	0.00%	0.00%
Health care trend rate	7.70%	7.00%
Year Health care cost trend rate reaches ultimate trend rate	2033	2031
Other Postretirement Benefits Plan | Net Period Benefit Cost/Credit
Weighted-Average Assumptions
Health care trend rate	7.20%	6.90%	7.00%
Health care trend rate	4.50%	4.40%	4.40%
Year Health care cost trend rate reaches ultimate trend rate	2028	2028	2028
Significant assumptions used to calculate NRG's benefit expense
Health care trend rate	7.20%	6.90%	7.00%
Year Health care cost trend rate reaches ultimate trend rate	2028	2028	2028

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Benefit Plans and Other Postretirement Benefits - Expected Future Benefit Payments for the Next Five Years and Other (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Company's contributions to 401(k) plans
Company contributions to defined contribution plans	$ 61	$ 37	$ 35
South Texas Project
STP Defined Benefit Plans
Amount reimbursed to STPNOC towards defined benefit plans	$ 3	18
STP
STP Defined Benefit Plans
Percentage of contribution to the retirement plan obligation reimbursed	44.00%
Benefit Payments
NRG's expected future benefit payments
2024	$ 82
2025	81
2026	79
2027	78
2028	76
2029-2033	360
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans	(172)	(192)
Net periodic benefit cost/(credit)	21	18	(27)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	(38)	57
Benefit Payments | South Texas Project
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans		(7)
Net periodic benefit cost/(credit)		2
Other changes in plan assets and benefit obligations recognized in other comprehensive income		(27)
Other Postretirement Benefits Plan
NRG's expected future benefit payments
2024	5
2025	5
2026	5
2027	5
2028	5
2029-2033	27
Medicare prescription drug reimbursements
2024	0
2025	0
2026	0
2027	0
2028	0
2029-2033	2
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans	(75)	(84)
Net periodic benefit cost/(credit)	(3)	(4)	$ (6)
Other changes in plan assets and benefit obligations recognized in other comprehensive income	$ 1	(5)
Other Postretirement Benefits Plan | South Texas Project
Recognized amount in statement of financial position, statement of operations and accumulated OCI related to STP
Funded status — STPNOC benefit plans		(13)
Net periodic benefit cost/(credit)		(4)
Other changes in plan assets and benefit obligations recognized in other comprehensive income		$ 1

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Capital Structure - Narrative (Details) - shares	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Equity [Abstract]
Preferred stock, shares authorized (in shares)	10,000,000	10,000,000	10,000,000	10,000,000
Common stock, shares authorized (in shares)	500,000,000	500,000,000	500,000,000	500,000,000

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Capital Structure - Changes in NRG's Common Stock Issued and Outstanding (Details) - shares		1 Months Ended	3 Months Ended	12 Months Ended
	Mar. 09, 2023	Jan. 31, 2024	Dec. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Schedule of Stock by Class, Equity [Roll Forward]
Preferred shares, balance beginning (in shares)		650,000		0
Preferred shares, outstanding, beginning balance (in shares)		650,000		0
Preferred shares, balance as of end of period (in shares)			650,000	650,000	0
Preferred shares, outstanding , ending balance (in shares)			650,000	650,000	0
Beginning balance, common shares issued (in shares)		267,330,470		423,897,001
Beginning balance, treasury shares (in shares)		(59,199,520)		(194,335,971)
Beginning balance, common shares outstanding (in shares)		208,130,950		229,561,030	243,753,899	244,231,933
Share repurchases (in shares)				(22,730,940)	(14,685,521)	(1,084,752)
Retirement of treasury stock (in shares)			157,676,142	0
Ending balance, common shares issued (in shares)			267,330,470	267,330,470	423,897,001
Ending balance, treasury shares (in shares)			(59,199,520)	(59,199,520)	(194,335,971)
Ending balance, common shares outstanding (in shares)			208,130,950	208,130,950	229,561,030	243,753,899
Subsequent Event
Schedule of Stock by Class, Equity [Roll Forward]
Share repurchases (in shares)		(770,205)
Ending balance, common shares outstanding (in shares)		208,021,012
Long-term Incentive Plan
Schedule of Stock by Class, Equity [Roll Forward]
Shares issued under LTIPs (in shares)				1,109,611	349,827	489,326
Long-term Incentive Plan | Subsequent Event
Schedule of Stock by Class, Equity [Roll Forward]
Shares issued under LTIPs (in shares)		660,267
Employee Stock Purchase Plan
Schedule of Stock by Class, Equity [Roll Forward]
Shares issued under ESPP (in shares)				191,249	142,825	117,392
Preferred Stock
Schedule of Stock by Class, Equity [Roll Forward]
Preferred shares, balance beginning (in shares)		650,000
Preferred shares, outstanding, beginning balance (in shares)		650,000
Preferred shares, balance as of end of period (in shares)			650,000	650,000
Preferred shares, outstanding , ending balance (in shares)			650,000	650,000
Preferred Stock | Subsequent Event
Schedule of Stock by Class, Equity [Roll Forward]
Preferred shares, balance as of end of period (in shares)		650,000
Preferred shares, outstanding , ending balance (in shares)		650,000
Preferred Stock | Series A Preferred Stock
Schedule of Stock by Class, Equity [Roll Forward]
Issuance of Series A Preferred Stock (in shares)	650,000			650,000
Common Stock
Schedule of Stock by Class, Equity [Roll Forward]
Beginning balance, common shares issued (in shares)		267,330,470		423,897,001	423,547,174	423,057,848
Beginning balance, common shares outstanding (in shares)		208,130,950
Retirement of treasury stock (in shares)					(157,676,142)
Ending balance, common shares issued (in shares)			267,330,470	267,330,470	423,897,001	423,547,174
Ending balance, common shares outstanding (in shares)			208,130,950	208,130,950
Common Stock | Subsequent Event
Schedule of Stock by Class, Equity [Roll Forward]
Shares issued under LTIPs (in shares)		660,267
Retirement of treasury stock (in shares)		(770,205)
Ending balance, common shares issued (in shares)		267,220,532
Common Stock | Long-term Incentive Plan
Schedule of Stock by Class, Equity [Roll Forward]
Shares issued under LTIPs (in shares)				1,109,611	349,827	489,326
Treasury Stock
Schedule of Stock by Class, Equity [Roll Forward]
Beginning balance, treasury shares (in shares)		(59,199,520)		(194,335,971)	(179,793,275)	(178,825,915)
Shares issued under ESPP (in shares)				191,249	142,825	117,392
Share repurchases (in shares)				(22,730,940)	(14,685,521)	(1,084,752)
Retirement of treasury stock (in shares)				157,676,142
Ending balance, treasury shares (in shares)			(59,199,520)	(59,199,520)	(194,335,971)	(179,793,275)
Treasury Stock | Subsequent Event
Schedule of Stock by Class, Equity [Roll Forward]
Shares issued under LTIPs (in shares)		0
Share repurchases (in shares)		(770,205)
Retirement of treasury stock (in shares)		770,205
Ending balance, treasury shares (in shares)		(59,199,520)
Treasury Stock | Long-term Incentive Plan
Schedule of Stock by Class, Equity [Roll Forward]
Shares issued under LTIPs (in shares)				0	0	0

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Capital Structure - Common Stock, Share Repurchases and Retirement of Treasury Stock (Details) - USD ($)								1 Months Ended		3 Months Ended			12 Months Ended
		Jan. 30, 2024	Jan. 19, 2024	Dec. 27, 2023	Nov. 08, 2023	Apr. 27, 2023	Apr. 01, 2023	Jan. 31, 2024	Jun. 30, 2023	Mar. 31, 2024	Dec. 31, 2023	Mar. 31, 2023	Dec. 31, 2023		Dec. 31, 2022	Dec. 31, 2021	Nov. 06, 2023	Jun. 22, 2023	Dec. 06, 2021
Equity, Class of Treasury Stock [Line Items]
Quarterly dividends per share (usd per share)													$ 0.3775		$ 0.350	$ 0.325
Dividends paid per share (in usd per share)													1.51		1.40	1.30
Common stock, dividends, proposed annual amount, per share (usd per share)													$ 1.30		$ 1.40	$ 1.51
Common stock, annual dividends increase, percentage													8.00%		8.00%	8.00%
Eligible compensation withholding, minimum, percentage													1.00%
Eligible compensation withholding, maximum, percentage													10.00%
Market value on offering date percentage													90.00%
Exercise price as a percentage of fair value (as a percent)							90.00%					95.00%	90.00%
Increase in shares available for issuance under the ESPP (in shares)						4,400,000
Treasury stock reserved for issuance under the ESPP (in shares)											6,702,125		6,702,125
Shares repurchased recorded in treasury													$ 1,160,000,000	[1]	$ 595,000,000	$ 44,000,000
Retirement of treasury stock (in shares)											157,676,142		0
Retirement of treasury stock											$ 5,000,000,000
Treasury Stock
Equity, Class of Treasury Stock [Line Items]
Shares repurchased recorded in treasury													$ 1,043,000,000	[1]	$ 595,000,000	$ 44,000,000
Retirement of treasury stock (in shares)													157,676,142
Retirement of treasury stock													$ (5,009,000,000)
Additional Paid-In Capital
Equity, Class of Treasury Stock [Line Items]
Shares repurchased recorded in treasury	[1]												117,000,000
Retirement of treasury stock													5,008,000,000
November 2023 Accelerated Share Repurchase Agreements
Equity, Class of Treasury Stock [Line Items]
Accelerated share repurchases, agreement amount																	$ 950,000,000
Accelerated share repurchases, paid																	$ (950,000,000)
Shares, repurchased (in shares)				13,181,918	4,494,224
November 2023 Accelerated Share Repurchase Agreements | Treasury Stock
Equity, Class of Treasury Stock [Line Items]
Shares repurchased recorded in treasury				$ 833,000,000
November 2023 Accelerated Share Repurchase Agreements | Additional Paid-In Capital
Equity, Class of Treasury Stock [Line Items]
Shares repurchased recorded in treasury				$ 117,000,000
2021 Capital Allocation Plan
Equity, Class of Treasury Stock [Line Items]
Stock repurchase program, authorized amount																			$ 1,000,000,000
2023 Capital Allocation Plan
Equity, Class of Treasury Stock [Line Items]
Stock repurchase program, authorized amount											$ 2,700,000,000		$ 2,700,000,000					$ 2,700,000,000
Target allocation, return to shareholders, percent of cash available									80.00%
Average price paid per share (in shares)													$ 39.56
Shares repurchased													$ 1,200,000,000
Open market repurchases
Equity, Class of Treasury Stock [Line Items]
Average price paid per share (in shares)															$ 40.48	$ 40.85
Shares repurchased													$ 200,000,000		$ 595,000,000	$ 44,000,000
Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Common stock, dividends, proposed annual amount, per share (usd per share)			$ 1.63
Dividends per common share (in usd per share)			$ 0.4075
Subsequent Event | Treasury Stock
Equity, Class of Treasury Stock [Line Items]
Retirement of treasury stock (in shares)								770,205
Subsequent Event | November 2023 Accelerated Share Repurchase Agreements
Equity, Class of Treasury Stock [Line Items]
Shares, repurchased (in shares)		770,205
Subsequent Event | 2023 Capital Allocation Plan
Equity, Class of Treasury Stock [Line Items]
Stock repurchase program, authorized amount								$ 2,700,000,000
Stock repurchase program, remaining amount								$ 1,500,000,000
Scenario, Plan | Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Common stock, dividends, proposed annual amount, per share (usd per share)										$ 1.63
Common stock, annual dividends increase, percentage										8.00%
Minimum
Equity, Class of Treasury Stock [Line Items]
Annual dividend growth rate, percentage													7.00%
Maximum
Equity, Class of Treasury Stock [Line Items]
Annual dividend growth rate, percentage													9.00%
Long-term incentive plans
Equity, Class of Treasury Stock [Line Items]
Long-term incentive plans (in shares)											27,362,083		27,362,083

[1] Includes excise tax accrued of $10 million as of December 31, 2023

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Capital Structure - Summary of Changes in Shares Repurchased (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended		12 Months Ended
	Feb. 01, 2024	Jan. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)			22,730,940	14,685,521	1,084,752
Shares repurchased, excise tax accrued			$ 10
Subsequent Event
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)		770,205
Open market repurchases
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)			5,054,798	14,685,521	1,084,752
Average price paid per share (in shares)				$ 40.48	$ 40.85
Amounts paid for shares purchased (in millions)			$ 200	$ 595	$ 44
Accrued stock repurchases					$ 5
Accelerated repurchase agreements
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)			17,676,142
Amounts paid for shares purchased (in millions)			$ 950
Accelerated repurchase agreements | Subsequent Event
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)	770,205
Amounts paid for shares purchased (in millions)	$ 0
Capital Allocation Plan
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)			22,730,940
Amounts paid for shares purchased (in millions)			$ 1,150
Capital Allocation Plan | Subsequent Event
Schedule of Capitalization, Equity [Line Items]
Total number of shares purchased (in shares)	23,501,145
Amounts paid for shares purchased (in millions)	$ 1,150

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Capital Structure - Preferred Stock (Details) - USD ($) $ / shares in Units, $ in Millions			1 Months Ended	12 Months Ended
		Mar. 09, 2023	Sep. 30, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Class of Stock [Line Items]
Proceeds from issuance of preferred stock				$ 635	$ 0	$ 0
Preferred stock, dividends (in usd per share)				$ 52.96
Preferred stock, dividends	[1]			$ 34
Series A Preferred Stock
Class of Stock [Line Items]
Preferred stock, dividends (in usd per share)			$ 52.96
Preferred stock, dividends			$ 34
Series A Preferred Stock | Preferred Stock
Class of Stock [Line Items]
Issuance of Series A Preferred Stock (in shares)		650,000		650,000
Preferred stock, dividend rate (as percent)		10.25%
Proceeds from issuance of preferred stock		$ 635
Series A Preferred Stock | Preferred Stock | US Treasury (UST) Interest Rate
Class of Stock [Line Items]
Preferred stock, liquidation preference (in usd per share)		$ 1,000
Preferred stock, dividend rate, floor		1.00%
Preferred stock, dividend rate, basis spread on variable rate		5.92%

[1] Dividend per Series A Preferred Stock was $52.96

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Investments Accounted for by the Equity Method and Variable Interest Entities - Summary of Equity Method Investments and Undistributed Earnings (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Investments Accounted for by the Equity Method
Equity investments in affiliates	$ 42	$ 133
Undistributed earnings from equity investment	$ 0	$ 42
Gladstone
Investments Accounted for by the Equity Method
Economic interest in equity method investments (as a percent)	37.50%
Equity investments in affiliates	$ 34
Midway-Sunset Cogeneration Company
Investments Accounted for by the Equity Method
Economic interest in equity method investments (as a percent)	50.00%
Equity investments in affiliates	$ 8

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Investments Accounted for by the Equity Method and Variable Interest Entities - Other Equity Investments (Details) $ in Millions	Dec. 31, 2023 USD ($) MW	Dec. 31, 2022 USD ($)
Schedule of Equity Method Investments [Line Items]
Generation capacity (in MW) | MW	13
Equity investments in affiliates | $	$ 42	$ 133
Gladstone
Schedule of Equity Method Investments [Line Items]
Ownership percentage	37.50%
Generation capacity (in MW) | MW	1,613
Equity investments in affiliates | $	$ 34

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Investments Accounted for by the Equity Method and Variable Interest Entities - Summarized Financial Information (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Current liabilities	$ 9,500	$ 12,982
Variable Interest Entity, Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Accounts receivable and Other current assets	1,541	2,108
Current liabilities	153	152
Net assets	$ 1,388	$ 1,956

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(Loss)/Income Per Share- Basic and Diluted EPS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Basic and diluted (loss)/income per share:
Net (Loss)/Income	$ (202)	$ 1,221	$ 2,187
Less: Cumulative dividends attributable to Series A Preferred Stock	54	0	0
Net (Loss)/ Income Available for Common Stockholders, basic	(256)	1,221	2,187
Net (Loss)/ Income Available for Common Stockholders, diluted	$ (256)	$ 1,221	$ 2,187
Weighted average number of common shares outstanding — basic (in shares)	228,000	236,000	245,000
Weighted average number of common shares outstanding — diluted (in shares)	228,000	236,000	245,000
(Loss)/Income per weighted average common share — basic (in usd per share)	$ (1.12)	$ 5.17	$ 8.93
(Loss)/Income per weighted average common share — diluted (in usd per share)	$ (1.12)	$ 5.17	$ 8.93

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(Loss)/Income Per Share - Narrative (Details) shares in Millions	12 Months Ended
	Dec. 31, 2023 shares
Earnings Per Share [Abstract]
Antidilutive securities (in shares)	6

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Segment Reporting (Details) - USD ($) $ in Millions	3 Months Ended				12 Months Ended
	Dec. 31, 2023	Sep. 30, 2022	Jun. 30, 2022	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Statement
Revenues					$ 28,823	$ 31,543	$ 26,989
Operating expenses					28,864	28,737	22,566
Depreciation and amortization					1,127	634	785
Impairment losses					26	206	544
Total operating cost and expenses					30,017	29,577	23,895
Gain on sale of assets					1,578	52	247
Operating income/(loss)					384	2,018	3,341
Equity in earnings of unconsolidated affiliates					16	6	17
Impairment losses on investments					(102)	0	0
Other income, net					47	56	63
Loss on debt extinguishment					109	0	(77)
Interest expense					(667)	(417)	(485)
(Loss)/Income Before Income Taxes					(213)	1,663	2,859
Income tax expense (benefit)					(11)	442	672
Net income (loss)					(202)	1,221	2,187
Balance sheet
Equity investments in affiliates	$ 42				42	133
Capital expenditures	598				598	367
Goodwill	5,079			$ 1,795	5,079	1,650	1,795
Total assets	26,038				26,038	29,146
Corporate
Income Statement
Revenues					0	0	0
Operating expenses					133	86	141
Depreciation and amortization					36	31	28
Impairment losses					0	0	0
Total operating cost and expenses					169	117	169
Gain on sale of assets					0	(3)	211
Operating income/(loss)					(169)	(120)	42
Equity in earnings of unconsolidated affiliates					0	0	0
Impairment losses on investments					0
Other income, net					56	54	59
Loss on debt extinguishment					109		(77)
Interest expense					(469)	(400)	(469)
(Loss)/Income Before Income Taxes					(473)	(466)	(445)
Income tax expense (benefit)					132	384	653
Net income (loss)					(605)	(850)	(1,098)
Balance sheet
Equity investments in affiliates	0				0	0
Capital expenditures	53				53	50
Goodwill	0				0	0
Total assets	19,919				19,919	35,780
Eliminations
Income Statement
Revenues					(30)	17	10
Operating expenses					(30)	17	10
Depreciation and amortization					0	0	0
Impairment losses					0	0	0
Total operating cost and expenses					(30)	17	10
Gain on sale of assets					0	0	0
Operating income/(loss)					0	0	0
Equity in earnings of unconsolidated affiliates					0	0	0
Impairment losses on investments					0
Other income, net					(16)	(16)	(14)
Loss on debt extinguishment					0		0
Interest expense					16	16	14
(Loss)/Income Before Income Taxes					0	0	0
Income tax expense (benefit)					0	0	0
Net income (loss)					0	0	0
Balance sheet
Equity investments in affiliates	0				0	0
Capital expenditures	0				0	0
Goodwill	0				0	0
Total assets	(26,498)				(26,498)	(45,774)
Texas
Income Statement
Impairment losses	2
Balance sheet
Goodwill	643			716	643	710	716
Texas | Operating Segments
Income Statement
Revenues					10,476	10,057	10,295
Operating expenses					8,407	8,495	8,692
Depreciation and amortization					294	310	336
Impairment losses					2	0	0
Total operating cost and expenses					8,703	8,805	9,028
Gain on sale of assets					1,319	10	19
Operating income/(loss)					3,092	1,262	1,286
Equity in earnings of unconsolidated affiliates					0	(2)	(3)
Impairment losses on investments					0
Other income, net					2	5	8
Loss on debt extinguishment					0		0
Interest expense					(3)	0	(1)
(Loss)/Income Before Income Taxes					3,091	1,265	1,290
Income tax expense (benefit)					0	0	0
Net income (loss)					3,091	1,265	1,290
Balance sheet
Equity investments in affiliates	0				0	0
Capital expenditures	495				495	273
Goodwill	643				643	710
Total assets	8,236				8,236	11,475
Texas | Eliminations
Income Statement
Revenues					(5)	(4)	(5)
East
Income Statement
Impairment losses	4	$ 43	$ 20	16		13
Balance sheet
Goodwill	721			853	721	723	853
East | Operating Segments
Income Statement
Revenues					12,547	16,763	13,025
Operating expenses					14,412	16,031	10,256
Depreciation and amortization					116	208	333
Impairment losses					4	206	535
Total operating cost and expenses					14,532	16,445	11,124
Gain on sale of assets					259	0	0
Operating income/(loss)					(1,726)	318	1,901
Equity in earnings of unconsolidated affiliates					0	0	0
Impairment losses on investments					0
Other income, net					11	10	7
Loss on debt extinguishment					0		0
Interest expense					(3)	(1)	(1)
(Loss)/Income Before Income Taxes					(1,718)	327	1,907
Income tax expense (benefit)					0	1	0
Net income (loss)					(1,718)	326	1,907
Balance sheet
Equity investments in affiliates	0				0	0
Capital expenditures	5				5	7
Goodwill	721				721	723
Total assets	13,712				13,712	19,526
East | Eliminations
Income Statement
Revenues					(9)	26	18
West/Services/Other
Balance sheet
Goodwill	221			226	221	217	226
West/Services/Other | Operating Segments
Income Statement
Revenues					4,281	4,706	3,659
Operating expenses					5,025	4,108	3,467
Depreciation and amortization					95	85	88
Impairment losses					20	0	9
Total operating cost and expenses					5,140	4,193	3,564
Gain on sale of assets					0	45	17
Operating income/(loss)					(859)	558	112
Equity in earnings of unconsolidated affiliates					16	8	20
Impairment losses on investments					(102)
Other income, net					6	3	3
Loss on debt extinguishment					0		0
Interest expense					(31)	(32)	(28)
(Loss)/Income Before Income Taxes					(970)	537	107
Income tax expense (benefit)					(111)	57	19
Net income (loss)					(859)	480	88
Balance sheet
Equity investments in affiliates	42				42	133
Capital expenditures	27				27	37
Goodwill	221				221	217
Total assets	3,626				3,626	8,139
West/Services/Other | Eliminations
Income Statement
Revenues					(16)	(5)	(3)
Vivint Smart Home
Balance sheet
Goodwill	3,494			$ 0	3,494	$ 0	$ 0
Vivint Smart Home | Operating Segments
Income Statement
Revenues					1,549
Operating expenses					917
Depreciation and amortization					586
Impairment losses					0
Total operating cost and expenses					1,503
Gain on sale of assets					0
Operating income/(loss)					46
Equity in earnings of unconsolidated affiliates					0
Impairment losses on investments					0
Other income, net					(12)
Loss on debt extinguishment					0
Interest expense					(177)
(Loss)/Income Before Income Taxes					(143)
Income tax expense (benefit)					(32)
Net income (loss)					(111)
Balance sheet
Equity investments in affiliates	0				0
Capital expenditures	18				18
Goodwill	3,494				3,494
Total assets	$ 7,043				7,043
Vivint Smart Home | Eliminations
Income Statement
Revenues					$ 0

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Income Taxes - Income Tax Provision (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Current
U.S. Federal	$ 26	$ 3	$ 0
State	84	65	48
Foreign	(12)	3	3
Total — current	98	71	51
Deferred
U.S. Federal	50	258	569
State	(61)	59	36
Foreign	(98)	54	16
Total — deferred	(109)	371	621
Total income tax (benefit)/expense	(11)	442	672
Domestic and foreign components of income from continuing operations before income tax expense
U.S.	261	1,436	2,759
Foreign	(474)	227	100
(Loss)/Income Before Income Taxes	(213)	1,663	2,859
Reconciliation of the U.S. federal statutory rate to NRG's effective rate from continuing operations
(Loss)/Income before income taxes	(213)	1,663	2,859
Tax at federal statutory tax rate	(45)	349	600
State taxes	(22)	69	111
Foreign operations	(10)	7	(3)
Changes in state valuation allowances	42	(3)	(29)
Permanent differences	31	17	8
Recognition of uncertain tax benefits	12	8	(10)
Deferred impact of state tax rate changes	3	14	(10)
Foreign tax refunds	(17)	0	0
Carbon capture tax credits	0	(19)	0
Return to provision adjustments	(5)	0	5
Total income tax (benefit)/expense	$ (11)	$ 442	$ 672
Effective income tax rate (as a percent)	5.20%	26.60%	23.50%

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Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Deferred tax assets:
U.S. Federal net operating loss carryforwards	$ 1,762	$ 1,717
State net operating loss carryforwards	367	315
Foreign net operating loss carryforwards	110	104
Deferred revenues	347	0
Difference between book and tax basis of property	353	399
Federal and state tax credit carryforwards	317	393
Deferred compensation, accrued vacation and other reserves	141	93
Interest disallowance carryforward per §163(j) of the Tax Act	132	65
Pension and other postretirement benefits	48	62
Allowance for credit losses	35	33
Equity compensation	24	8
Federal benefit on state uncertain tax positions	13	5
Inventory obsolescence	11	10
U.S. capital loss	1	15
Other	33	22
Total deferred tax assets	3,694	3,241
Deferred tax liabilities:
Intangibles amortization (excluding goodwill)	726	269
Derivatives	156	874
Capitalized contract costs	131	0
Equity method investments	93	82
Goodwill	40	26
Debt discount amortization	26	0
Emissions allowances	18	19
Total deferred tax liabilities	1,190	1,270
Total deferred tax assets less deferred tax liabilities	2,504	1,971
Valuation allowance	(275)	(224)
Net deferred tax asset	2,229	1,747
NRG's net deferred tax position
Deferred tax asset	2,251	1,881
Deferred tax liability	(22)	(134)
Net deferred tax asset	$ 2,229	$ 1,747

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Income Taxes - Narrative for Deferred Tax Assets and Valuation Allowance, Taxes Receivable and Payable (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Taxes receivable and payable
Deferred tax asset	$ 2,229	$ 1,747
Deferred tax asset, net (before valuation allowance)	2,504	1,971
Valuation allowance	275	$ 224
Federal Tax Authority
Taxes receivable and payable
Operating loss carryforwards	1,800
Current taxes payable	20
State and Local Jurisdiction
Taxes receivable and payable
Operating loss carryforwards	367
Current taxes payable	3
Foreign Tax Authority
Taxes receivable and payable
Operating loss carryforwards	110
Current net federal tax receivable	$ 7

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Income Taxes - Reconciliation of Uncertain Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Uncertain tax benefits
Uncertain tax benefits	$ 73	$ 22
Liability for uncertainty in income taxes, noncurrent	76	24
Unrecognized tax benefits, income tax penalties expense	1	1
Accrued interest and penalties related to unrecognized tax benefits	3	2
Uncertain tax benefits reconciliation
Balance as of January 1	22	13
Increase due to current year positions	28	9
Increase due to acquired balance from Vivint Smart Home	23	0
Uncertain tax benefits as of December 31	$ 73	$ 22

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Stock-Based Compensation - Long-Term Incentive Plan (Details) - NRG LTIP - shares	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized for issuance under plan (in shares)	25,000,000	25,000,000
Number of shares available for grant under plan (in shares)	7,717,139	8,179,771

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Stock-Based Compensation - Restricted Stock Units (RSUs) (Details) - Restricted Stock Units - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Stock-Based Compensation
Award vesting period	3 years
Units
Non-vested at beginning of period (in shares)	856,917
Granted (in shares)	1,031,469
Forfeited (in shares)	(284,076)
Vested (in shares)	(393,470)
Non-vested at end of period (in shares)	1,210,840	856,917
Weighted Average Grant Date Fair Value per Unit
Non-vested at beginning of period (in usd per share)	$ 40.25
Granted (in usd per share)	35.71	$ 41.26	$ 39.00
Forfeited (in usd per share)	34.70
Vested (in usd per share)	39.67
Non-vested at end of period (in usd per share)	$ 37.88	$ 40.25
Vested in period, fair value	$ 20	$ 10	$ 12
Weighted average grant date fair value (in usd per share)	$ 35.71	$ 41.26	$ 39.00

XML

Stock-Based Compensation - Deferred Stock Units (DSUs) (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Stock-Based Compensation
Participant right to receive common stock at end of deferral period (in shares)	1
DSUs
Units
Balance outstanding at the beginning of the period (in shares)	418,014
Granted (in shares)	79,072
Converted to Common Stock (in shares)	(53,799)
Balance outstanding at the end of the period (in shares)	443,287	418,014
Weighted Average Grant Date Fair Value per Unit
Balance outstanding at the beginning of the period, (in usd per share)	$ 27.63
Granted (in usd per share)	34.40	$ 45.49	$ 32.27
Vested (in usd per share)	25.11
Balance outstanding at the end of the period (in usd per share)	$ 29.07	$ 27.63
Aggregate intrinsic value for DSUs outstanding	$ 23	$ 13	$ 17
Aggregate intrinsic values for DSUs converted to common stock during the period	$ 3	$ 1	$ 1
Weighted average grant date fair value (in usd per share)	$ 34.40	$ 45.49	$ 32.27

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Stock -Based Compensation - Performance Stock Units, RPSUs Plan Description (Details) - RPSUs	12 Months Ended
	Dec. 31, 2023
Stock-Based Compensation
Award vesting period	3 years
Share-based Payment Arrangement, Tranche One
Stock-Based Compensation
Award vesting right, percentage	0.00%
Share-based Payment Arrangement, Tranche Two
Stock-Based Compensation
Award vesting right, percentage	25.00%
Share-based Payment Arrangement, Tranche Three
Stock-Based Compensation
Award vesting right, percentage	100.00%
Share-based Payment Arrangement, Tranche Four
Stock-Based Compensation
Award vesting right, percentage	15.00%
Share-based Payment Arrangement, Tranche Five
Stock-Based Compensation
Award vesting right, percentage	200.00%

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Stock-Based Compensation - Relative Performance Stock Units (Details) - RPSUs - $ / shares	1 Months Ended	12 Months Ended
	Sep. 30, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Units
Non-vested at beginning of period (in shares)		795,335
Granted (in shares)	60,815	617,510
Forfeited (in shares)		(737,227)
Vested (in shares)		(3,729)
Non-vested at end of period (in shares)		671,889	795,335
Weighted Average Grant-Date Fair Value per Unit
Non-vested at beginning of period (in usd per share)		$ 50.23
Granted (in usd per share)		39.46	$ 57.41	$ 46.78
Forfeited (in usd per share)		45.61
Vested (in usd per share)		50.28
Non-vested at end of period (in usd per share)		$ 46.27	$ 50.23
Payout percentage		0.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Expected volatility	37.38%	41.35%	37.54%	34.05%
Expected term (in years)		3 years	3 years	3 years
Risk free rate	0.42%	4.18%	0.97%	0.17%

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Stock-Based Compensation - Vivint Long-Term Incentive Plan Narrative (Details)	12 Months Ended
	Dec. 31, 2023 shares
Vivint LTIP
Stock-Based Compensation
Number of shares authorized for issuance under plan (in shares)	17,500,000
Number of shares available for grant under plan (in shares)	12,749,736
Restricted Stock Units
Stock-Based Compensation
Award vesting period	3 years
Restricted Stock Units | Vivint LTIP
Stock-Based Compensation
Award vesting period	4 years

XML

Stock-Based Compensation - Summary of Vivint RSUs (Details) - USD ($) $ / shares in Units, $ in Millions		10 Months Ended	12 Months Ended
	Mar. 10, 2023	Dec. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Rollover RSUs | Vivint LTIP
Units
Non-vested at beginning of period (in shares)			0
Rolled over at the acquisition date (in shares)	4,553,998
Granted (in shares)		0
Forfeited (in shares)		(288,776)
Vested (in shares)		(1,280,321)
Non-vested at end of period (in shares)		2,984,901	2,984,901	0
Weighted Average Grant Date Fair Value per Unit
Non-vested at beginning of period (in usd per share)			$ 0
Rolled over at the acquisition date (in usd per share)	$ 31.63
Granted (in usd per share)		$ 0
Forfeited (in usd per share)		31.63
Vested (in usd per share)		31.63
Non-vested at end of period (in usd per share)		$ 31.63	$ 31.63	$ 0
Restricted Stock Units -after Acquisition | Vivint LTIP
Units
Granted (in shares)		895,827
Forfeited (in shares)		(110,531)
Vested (in shares)		(4,998)
Non-vested at end of period (in shares)		780,298	780,298
Weighted Average Grant Date Fair Value per Unit
Granted (in usd per share)		$ 35.24
Forfeited (in usd per share)		35.21
Vested (in usd per share)		35.21
Non-vested at end of period (in usd per share)		$ 35.24	$ 35.24
Restricted Stock Units
Units
Non-vested at beginning of period (in shares)			856,917
Granted (in shares)			1,031,469
Forfeited (in shares)			(284,076)
Vested (in shares)			(393,470)
Non-vested at end of period (in shares)		1,210,840	1,210,840	856,917
Weighted Average Grant Date Fair Value per Unit
Non-vested at beginning of period (in usd per share)			$ 40.25
Granted (in usd per share)			35.71	$ 41.26	$ 39.00
Forfeited (in usd per share)			34.70
Vested (in usd per share)			39.67
Non-vested at end of period (in usd per share)		$ 37.88	$ 37.88	$ 40.25
Vested in period, fair value			$ 20	$ 10	$ 12
Restricted Stock Units | Vivint LTIP
Weighted Average Grant Date Fair Value per Unit
Vested in period, fair value			$ 66

XML

Stock-Based Compensation - PSUs Granted Under Vivint LTIP (Details) - PSUs - Vivint LTIP	12 Months Ended
	Dec. 31, 2023 $ / shares shares
Stock-Based Compensation
Granted (in shares) | shares	102,837
Outstanding at end of period (in shares) | shares	102,837
Granted (in usd per share) | $ / shares	$ 44.96
Non-vested at end of period (in usd per share) | $ / shares	$ 44.96

XML

Stock-Based Compensation - Supplemental Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Stock-Based Compensation
Minimum tax withholdings	$ 22	$ 6	$ 9
Compensation Expense	123	34	27
Tax detriment recognized	2	3	2
Unrecognized Total Cost	147
RSUs
Stock-Based Compensation
Compensation Expense	20	15	9
Unrecognized Total Cost	$ 29
Weighted Average Recognition Period Remaining (In years)	1 year 7 months 9 days
Award vesting period	3 years
RSUs | Vivint LTIP
Stock-Based Compensation
Compensation Expense	$ 76	0	0
Unrecognized Total Cost	$ 69
Weighted Average Recognition Period Remaining (In years)	1 year 9 months 25 days
Award vesting period	4 years
PSUs | Vivint LTIP
Stock-Based Compensation
Compensation Expense	$ 2	0	0
Unrecognized Total Cost	$ 3
Weighted Average Recognition Period Remaining (In years)	2 years 3 months
DSUs
Stock-Based Compensation
Compensation Expense	$ 2	2	2
Unrecognized Total Cost	$ 0
Weighted Average Recognition Period Remaining (In years)	0 years
RPSUs
Stock-Based Compensation
Compensation Expense	$ 3	11	9
Unrecognized Total Cost	$ 17
Weighted Average Recognition Period Remaining (In years)	1 year 8 months 8 days
Award vesting period	3 years
PRSUs
Stock-Based Compensation
Compensation Expense	$ 8	0	0
Unrecognized Total Cost	$ 14
Weighted Average Recognition Period Remaining (In years)	2 years 3 months 14 days
Award vesting period	3 years
PRSUs | NRG LTIP
Stock-Based Compensation
Compensation Expense	$ 12	$ 6	$ 7
Unrecognized Total Cost	$ 15
Weighted Average Recognition Period Remaining (In years)	1 year 8 months 26 days

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Related Party Transactions - Summary of Material Related Party Transactions with Third Party Affiliates (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Revenues	$ 28,823	$ 31,543	$ 26,989
Related Party
Related Party Transaction [Line Items]
Revenues	84	52	49
Related Party | Gladstone
Related Party Transaction [Line Items]
Revenues	4	4	4
Related Party | Ivanpah
Related Party Transaction [Line Items]
Revenues	78	42	39
Related Party | Midway-Sunset Cogeneration Company
Related Party Transaction [Line Items]
Revenues	$ 2	$ 6	$ 6

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Commitments and Contingencies - Minimum Commitments Under Outstanding Agreements (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Minimum purchase commitment
2024	$ 573
2025	836
2026	540
2027	364
2028	292
Thereafter	823
Total	3,428
Short-term commitments	978
Purchases under energy contracts	$ 13,400	$ 19,600	$ 13,400

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Commitments and Contingencies - Narrative (Details) $ in Millions		1 Months Ended
	Oct. 23, 2023 USD ($)	Feb. 28, 2023 USD ($)	Dec. 31, 2023 case	Nov. 01, 2023	Jul. 31, 2023	May 31, 2023 facility	Oct. 31, 2021 facility	Jun. 30, 2019 facility
Loss Contingencies [Line Items]
Number of facilities | facility						2	2
STP
Loss Contingencies [Line Items]
Ownership percentage			44.00%	44.00%
Pending Litigation
Loss Contingencies [Line Items]
Number of class action lawsuits | case			3
Sierra Club Et Al V. Midwest Generation L L C
Loss Contingencies [Line Items]
Number of facilities | facility								4
Direct Energy vs. Stanley, Forte, Schafer and Lane
Loss Contingencies [Line Items]
Number of class action lawsuits | case			1
Direct Energy vs. Burk and Dickson Litigation
Loss Contingencies [Line Items]
Number of class action lawsuits | case			2
CPI Security Systems, Inc.
Loss Contingencies [Line Items]
Damages awarded | $		$ 50
Punitive damages awarded | $		$ 140
SB IP Holdings LLC (Skybell) v. Vivint Smart Home, Inc.
Loss Contingencies [Line Items]
Damages awarded | $	$ 45
Partners in STP, CPS and Austin Energy vs. NRG | Pending Litigation | STP
Loss Contingencies [Line Items]
Ownership percentage					44.00%

XML

Regulatory Matters (Details) $ in Millions	Jan. 08, 2024 benefitPlan retailSupplier	May 03, 2021 USD ($)
Subsequent Event | New York State Public Service Commission
Loss Contingencies [Line Items]
Number of company's retail suppliers notified | retailSupplier	8
Subsequent Event | New York State Public Service Commission | Low
Loss Contingencies [Line Items]
Number of compliant products authorized by regulatory agency	1
Subsequent Event | New York State Public Service Commission | Maximum
Loss Contingencies [Line Items]
Number of compliant products authorized by regulatory agency	3
Vivint Smart Home
Loss Contingencies [Line Items]
Settlement for potential violations with FTC | $		$ 20

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Environmental Matters (Details) $ in Millions	Dec. 31, 2023 USD ($)	May 31, 2023 facility	Oct. 31, 2021 facility
Environmental Remediation Obligations [Abstract]
Environmental proceedings, disclosure threshold | $	$ 1
Number of facilities | facility		2	2

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Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Supplemental Cash Flow Information [Abstract]
Interest paid, net of amount capitalized	$ 548	$ 383	$ 433
Income taxes paid, net of refunds	48	66	32
Decreases to fixed assets for accrued capital expenditures	$ 0	$ (68)	$ (16)

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Guarantees - Schedule of Maximum Potential Exposure (Details) - USD ($) $ in Millions	Dec. 31, 2023	Dec. 31, 2022
Guarantor Obligations
Under 1 Year	$ 4,568
1-3 Years	61
3-5 Years	22
Over 5 Years	94
Guarantees by Remaining Maturity, Total	4,745	$ 5,635
Letters of credit and surety bonds
Guarantor Obligations
Under 1 Year	4,555
1-3 Years	37
3-5 Years	0
Over 5 Years	0
Guarantees by Remaining Maturity, Total	4,592	5,211
Asset sales guarantee obligations
Guarantor Obligations
Under 1 Year	13
1-3 Years	24
3-5 Years	22
Over 5 Years	67
Guarantees by Remaining Maturity, Total	126	409
Other guarantees
Guarantor Obligations
Under 1 Year	0
1-3 Years	0
3-5 Years	0
Over 5 Years	27
Guarantees by Remaining Maturity, Total	$ 27	$ 15

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Guarantees - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Guarantor Obligations
Guarantee obligation	$ 4,745	$ 5,635
Letters of credit and surety bonds
Guarantor Obligations
Guarantee obligation	$ 4,592	5,211
Letters of credit and surety bonds, maximum expiration period (in years)	1 year
Asset sales guarantee obligations
Guarantor Obligations
Guarantee obligation	$ 126	409
California property tax indemnity		$ 126

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Jointly Owned Plant (Details) - Cedar Bayou Unit 4, Baytown, TX $ in Millions	Dec. 31, 2023 USD ($)
Jointly Owned Utility Plant Interests
Ownership Interest (as a percent)	50.00%
Property, Plant & Equipment	$ 222
Accumulated Depreciation	(115)
Construction in Progress	$ 2

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SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Allowance for credit losses, deducted from accounts receivable and other non-current assets
Income tax valuation allowance, deducted from deferred tax assets
Balance at Beginning of Period	$ 133	$ 683	$ 67
Charged to Costs and Expenses	251	11	698
Charged to Other Accounts	35	0	112
Deductions	(274)	(561)	(194)
Balance at End of Period	145	133	683
Income tax valuation allowance, deducted from deferred tax assets
Income tax valuation allowance, deducted from deferred tax assets
Balance at Beginning of Period	224	248	266
Charged to Costs and Expenses	42	(20)	(29)
Charged to Other Accounts	9	(4)	11
Deductions	0	0	0
Balance at End of Period	$ 275	$ 224	$ 248

XML

Label	Element	Value
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2020-06 [Member]