Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDED June 30, 2021

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM          TO

Commission<br>File Number	Name of Registrant, Address, and Telephone Number			State or other jurisdiction of Incorporation or Organization	I.R.S. Employer<br>Identification  Number
001-09120	Public Service Enterprise Group Incorporated			New Jersey	22-2625848
	80 Park Plaza
	Newark,	New Jersey	07102
	973	430-7000
001-00973	Public Service Electric and Gas Company			New Jersey	22-1212800
	80 Park Plaza
	Newark,	New Jersey	07102
	973	430-7000
001-34232	PSEG Power LLC			Delaware	22-3663480
	80 Park Plaza
	Newark,	New Jersey	07102
	973	430-7000

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

Title of Each Class	Trading Symbol(s)	Name of Each Exchange<br>On Which Registered
Public Service Enterprise Group Incorporated
Common Stock without par value	PEG	New York Stock Exchange
Public Service Electric and Gas Company
8.00% First and Refunding Mortgage Bonds, due 2037	PEG37D	New York Stock Exchange
5.00% First and Refunding Mortgage Bonds, due 2037	PEG37J	New York Stock Exchange
PSEG Power LLC
8.625% Senior Notes, due 2031	PEG31	New York Stock Exchange

Indicate by check mark whether the registrants (1) have 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 registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). Yes ☒ No ☐

(Cover continued on next page)

Table of Contents

(Cover continued from previous page)

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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.

Public Service Enterprise Group Incorporated	Large accelerated filer	☒	Accelerated filer	☐	Non-accelerated filer	☐	Smaller reporting company	☐	Emerging growth company	☐
Public Service Electric and Gas Company	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
PSEG Power LLC	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐

If any of the registrants is an emerging growth company, indicate by check mark if such 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 any of the registrants is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of July 20, 2021, Public Service Enterprise Group Incorporated had outstanding 505,577,072 shares of its sole class of Common Stock, without par value.

As of July 20, 2021, Public Service Electric and Gas Company had issued and outstanding 132,450,344 shares of Common Stock, without nominal or par value, all of which were privately held, beneficially and of record, by Public Service Enterprise Group Incorporated.

Public Service Electric and Gas Company and PSEG Power LLC are wholly owned subsidiaries of Public Service Enterprise Group Incorporated and meet the conditions set forth in General Instruction H(1) of Form 10-Q. Each is filing its Quarterly Report on Form 10-Q with the reduced disclosure format authorized by General Instruction H.

Table of Contents

		Page
FORWARD-LOOKING STATEMENTS		ii
FILING FORMAT		iii
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements
	Public Service Enterprise Group Incorporated	1
	Public Service Electric and Gas Company	7
	PSEG Power LLC	13
	Notes to Condensed Consolidated Financial Statements
	Note 1. Organization, Basis of Presentation and Significant Accounting Policies	19
	Note 2. Recent Accounting Standards	20
	Note 3. Revenues	22
	Note 4. Early Plant Retirements/Asset Dispositions and Impairments	28
	Note 5. Variable Interest Entities (VIEs)	29
	Note 6. Rate Filings	30
	Note 7. Leases	31
	Note 8. Financing Receivables	32
	Note 9. Trust Investments	33
	Note 10. Pension and Other Postretirement Benefits (OPEB)	39
	Note 11. Commitments and Contingent Liabilities	41
	Note 12. Debt and Credit Facilities	47
	Note 13. Financial Risk Management Activities	48
	Note 14. Fair Value Measurements	53
	Note 15. Other Income (Deductions)	60
	Note 16. Income Taxes	61
	Note 17. Accumulated Other Comprehensive Income (Loss), Net of Tax	63
	Note 18. Earnings Per Share (EPS) and Dividends	67
	Note 19. Financial Information by Business Segment	68
	Note 20. Related-Party Transactions	69
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	71
	Executive Overview of 2021 and Future Outlook	71
	Results of Operations	80
	Liquidity and Capital Resources	86
	Capital Requirements	89
	Accounting Matters	89
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	89
Item 4.	Controls and Procedures	90
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	91
Item 1A.	Risk Factors	91
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	91
Item 5.	Other Information	91
Item 6.	Exhibits	93
	Signatures	95

i

Table of Contents

FORWARD-LOOKING STATEMENTS

Certain of the matters discussed in this report about our and our subsidiaries’ future performance, including, without limitation, future revenues, earnings, strategies, prospects, consequences and all other statements that are not purely historical constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Such forward-looking statements are subject to risks and uncertainties, which could cause actual results to differ materially from those anticipated. Such statements are based on management’s beliefs as well as assumptions made by and information currently available to management. When used herein, the words “anticipate,” “intend,” “estimate,” “believe,” “expect,” “plan,” “should,” “hypothetical,” “potential,” “forecast,” “project,” variations of such words and similar expressions are intended to identify forward-looking statements. Factors that may cause actual results to differ are often presented with the forward-looking statements themselves. Other factors that could cause actual results to differ materially from those contemplated in any forward-looking statements made by us herein are discussed in filings we make with the United States Securities and Exchange Commission (SEC), including our Annual Report on Form 10-K and subsequent reports on Form 10-Q and Form 8-K. These factors include, but are not limited to:

•any inability to successfully develop, obtain regulatory approval for, or construct generation, transmission and distribution projects;

•lack of growth or slower growth in the number of customers or the failure of our Conservation Incentive Program to fully address a decline in customer demand;

•any equipment failures, accidents, severe weather events, acts of war or terrorism or other incidents, including pandemics such as the ongoing coronavirus pandemic, that may impact our ability to provide safe and reliable service to our customers;

•any inability to recover the carrying amount of our long-lived assets;

•any inability to maintain sufficient liquidity;

•the impact of cybersecurity attacks or intrusions;

•the impact of the ongoing coronavirus pandemic;

•the impact of our covenants in our debt instruments on our operations;

•adverse performance of our nuclear decommissioning and defined benefit plan trust fund investments and changes in funding requirements;

•risks associated with the timeline and ultimate outcome of our exploration of strategic alternatives relating to PSEG Power’s non-nuclear generating fleet;

•the failure to complete, or delays in completing, our proposed investment in the Ocean Wind offshore wind project, or following the completion of our initial investment in the project, the failure to realize the anticipated strategic and financial benefits of the project;

•fluctuations in wholesale power and natural gas markets, including the potential impacts on the economic viability of our generation units;

•our ability to obtain adequate fuel supply;

•market risks impacting the operation of our generating stations;

•changes in technology related to energy generation, distribution and consumption and changes in customer usage patterns;

•third-party credit risk relating to our sale of generation output and purchase of fuel;

•any inability of PSEG Power to meet its commitments under forward sale obligations;

•reliance on transmission facilities to maintain adequate transmission capacity for our power generation fleet;

•the impact of changes in state and federal legislation and regulations on our business, including PSE&G’s ability to recover costs and earn returns on authorized investments;

•PSE&G’s proposed investment programs may not be fully approved by regulators and its capital investment may be lower than planned;

ii

Table of Contents

•the absence of a long-term legislative or other solution for our New Jersey nuclear plants that sufficiently values them for their carbon-free, fuel diversity and resilience attributes, or the impact of the current or subsequent payments for such attributes being materially adversely modified through legal proceedings;

•adverse changes in energy industry laws, policies and regulations, including market structures and transmission planning and transmission returns;

•risks associated with our ownership and operation of nuclear facilities, including regulatory risks, such as compliance with the Atomic Energy Act and trade control, environmental and other regulations, as well as financial, environmental and health and safety risks;

•changes in federal and state environmental regulations and enforcement; and

•delays in receipt of, or an inability to receive, necessary licenses and permits.

All of the forward-looking statements made in this report are qualified by these cautionary statements and we cannot assure you that the results or developments anticipated by management will be realized or even if realized, will have the expected consequences to, or effects on, us or our business, prospects, financial condition, results of operations or cash flows. Readers are cautioned not to place undue reliance on these forward-looking statements in making any investment decision. Forward-looking statements made in this report apply only as of the date of this report. While we may elect to update forward-looking statements from time to time, we specifically disclaim any obligation to do so, even in light of new information or future events, unless otherwise required by applicable securities laws.

The forward-looking statements contained in this report are intended to qualify for the safe harbor provisions of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended.

FILING FORMAT

This combined Quarterly Report on Form 10-Q is separately filed by Public Service Enterprise Group Incorporated (PSEG), Public Service Electric and Gas Company (PSE&G) and PSEG Power LLC (PSEG Power). Information relating to any individual company is filed by such company on its own behalf. PSE&G and PSEG Power are each only responsible for information about itself and its subsidiaries.

Discussions throughout the document refer to PSEG and its direct operating subsidiaries, PSE&G and PSEG Power. Depending on the context of each section, references to “we,” “us,” and “our” relate to PSEG or to the specific company or companies being discussed.

iii

Table of Contents

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

Millions, except per share data

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
OPERATING REVENUES	$	1,874	$	2,050	$	4,763	$	4,831
OPERATING EXPENSES
Energy Costs	606		595		1,635		1,501
Operation and Maintenance	783		733		1,561		1,487
Depreciation and Amortization	322		315		663		639
(Gains) Losses on Asset Dispositions and Impairments	457		—		457		—
Total Operating Expenses	2,168		1,643		4,316		3,627
OPERATING INCOME (LOSS)	(294)		407		447		1,204
Income from Equity Method Investments	6		3		9		6
Net Gains (Losses) on Trust Investments	81		201		141		(20)
Other Income (Deductions)	33		38		58		42
Net Non-Operating Pension and Other Postretirement Benefit (OPEB) Credits (Costs)	82		62		164		124
Interest Expense	(147)		(151)		(293)		(304)
INCOME (LOSS) BEFORE INCOME TAXES	(239)		560		526		1,052
Income Tax Benefit (Expense)	62		(109)		(55)		(153)
NET INCOME (LOSS)	$	(177)	$	451	$	471	$	899
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
BASIC	504		504		504		504
DILUTED	504		507		507		507
NET INCOME (LOSS) PER SHARE:
BASIC	$	(0.35)	$	0.89	$	0.94	$	1.78
DILUTED	$	(0.35)	$	0.89	$	0.93	$	1.77

See Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

Millions

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
NET INCOME (LOSS)	$	(177)	$	451	$	471	$	899
Other Comprehensive Income (Loss), net of tax
Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit of $(10), $(12), $16 and $(18) for the three and six months ended 2021 and 2020, respectively	16		20		(26)		28
Unrealized Gains (Losses) on Cash Flow Hedges, net of tax (expense) benefit of $(1), $(1), $(1) and $0 for the three and six months ended 2021 and 2020, respectively	—		3		1		—
Pension/OPEB adjustment, net of tax (expense) benefit of $(1), $(1), $(3) and $(2) for the three and six months ended 2021 and 2020, respectively	4		3		7		6
Other Comprehensive Income (Loss), net of tax	20		26		(18)		34
COMPREHENSIVE INCOME (LOSS)	$	(157)	$	477	$	453	$	933

See Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED

CONDENSED CONSOLIDATED BALANCE SHEETS

Millions

(Unaudited)

	June 30,<br>2021		December 31,<br>2020
ASSETS
CURRENT ASSETS
Cash and Cash Equivalents	$	107	$	543
Accounts Receivable, net of allowance of $251 in 2021 and $196 in 2020	1,408		1,410
Tax Receivable	9		63
Unbilled Revenues, net of allowance of $9 in 2021 and $10 in 2020	207		229
Fuel	207		277
Materials and Supplies, net	612		601
Prepayments	253		51
Derivative Contracts	35		60
Regulatory Assets	321		369
Other	42		27
Total Current Assets	3,201		3,630
PROPERTY, PLANT AND EQUIPMENT	48,270		48,569
Less: Accumulated Depreciation and Amortization	(11,226)		(10,984)
Net Property, Plant and Equipment	37,044		37,585
NONCURRENT ASSETS
Regulatory Assets	3,945		3,872
Operating Lease Right-of-Use Assets	214		262
Long-Term Investments	593		536
Nuclear Decommissioning Trust (NDT) Fund	2,628		2,501
Long-Term Tax Receivable	47		—
Long-Term Receivable of Variable Interest Entity (VIE)	954		945
Rabbi Trust Fund	245		266
Other Intangibles	122		158
Derivative Contracts	8		9
Other	291		286
Total Noncurrent Assets	9,047		8,835
TOTAL ASSETS	$	49,292	$	50,050

See Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED

CONDENSED CONSOLIDATED BALANCE SHEETS

Millions

(Unaudited)

	June 30,<br>2021		December 31,<br>2020
LIABILITIES AND CAPITALIZATION
CURRENT LIABILITIES
Long-Term Debt Due Within One Year	$	345	$	1,684
Commercial Paper and Loans	1,450		1,063
Accounts Payable	1,146		1,332
Derivative Contracts	34		21
Accrued Interest	126		126
Accrued Taxes	235		124
Clean Energy Program	231		143
Obligation to Return Cash Collateral	101		98
Regulatory Liabilities	301		294
Other	523		637
Total Current Liabilities	4,492		5,522
NONCURRENT LIABILITIES
Deferred Income Taxes and Investment Tax Credits (ITC)	6,219		6,502
Regulatory Liabilities	2,628		2,707
Operating Leases	204		252
Asset Retirement Obligations	1,270		1,212
OPEB Costs	722		730
OPEB Costs of Servco	714		699
Accrued Pension Costs	1,030		1,128
Accrued Pension Costs of Servco	220		226
Environmental Costs	237		286
Derivative Contracts	6		4
Long-Term Accrued Taxes	90		88
Other	232		214
Total Noncurrent Liabilities	13,572		14,048
COMMITMENTS AND CONTINGENT LIABILITIES (See Note 11)
CAPITALIZATION
LONG-TERM DEBT	15,350		14,496
STOCKHOLDERS’ EQUITY
Common Stock, no par, authorized 1,000 shares; issued, 2021 and 2020—534 shares	5,026		5,031
Treasury Stock, at cost, 2021 and 2020—30 shares	(899)		(861)
Retained Earnings	12,273		12,318
Accumulated Other Comprehensive Loss	(522)		(504)
Total Stockholders’ Equity	15,878		15,984
Total Capitalization	31,228		30,480
TOTAL LIABILITIES AND CAPITALIZATION	$	49,292	$	50,050

See Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

Millions

(Unaudited)

	Six Months Ended
	June 30,
	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$	471	$	899
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	663		639
Amortization of Nuclear Fuel	94		93
(Gains) Losses on Asset Dispositions and Impairments	457		—
Emission Allowances and Renewable Energy Credit (REC) Compliance Accrual	82		65
Provision for Deferred Income Taxes (Other than Leases) and ITC	(205)		104
Non-Cash Employee Benefit Plan (Credits) Costs	(89)		(52)
Leveraged Lease (Income), (Gains) and Losses, Adjusted for Rents Received and Deferred Taxes	6		9
Net Realized and Unrealized (Gains) Losses on Energy Contracts and Other Derivatives	331		(1)
Cost of Removal	(60)		(44)
Net Change in Regulatory Assets and Liabilities	(24)		(70)
Net (Gains) Losses and (Income) Expense from NDT Fund	(158)		5
Net Change in Certain Current Assets and Liabilities:
Tax Receivable	56		16
Prepayments	(200)		(158)
Accrued Taxes	30		115
Cash Collateral	(289)		32
Other Current Assets and Liabilities	(121)		98
Employee Benefit Plan Funding and Related Payments	(8)		(6)
Other	13		(80)
Net Cash Provided By (Used In) Operating Activities	1,049		1,664
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to Property, Plant and Equipment	(1,303)		(1,414)
Purchase of Emission Allowances and RECs	(34)		(50)
Proceeds from Sales of Trust Investments	1,229		1,163
Purchases of Trust Investments	(1,223)		(1,184)
Proceeds from Sales of Long-Lived Assets and Lease Investments	565		—
Other	(27)		52
Net Cash Provided By (Used In) Investing Activities	(793)		(1,433)
CASH FLOWS FROM FINANCING ACTIVITIES
Net Change in Commercial Paper and Loans	(563)		(750)
Proceeds from Short-Term Loans	1,250		800
Payment of Short-Term Loans	(300)		—
Issuance of Long-Term Debt	900		975
Redemption of Long-Term Debt	(1,384)		(406)
Cash Dividends Paid on Common Stock	(516)		(495)
Other	(71)		(64)
Net Cash Provided By (Used In) Financing Activities	(684)		60
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(428)		291
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	572		176
Cash, Cash Equivalents and Restricted Cash at End of Period	$	144	$	467
Supplemental Disclosure of Cash Flow Information:
Income Taxes Paid (Received)	$	143	$	41
Interest Paid, Net of Amounts Capitalized	$	279	$	288
Accrued Property, Plant and Equipment Expenditures	$	309	$	331

See Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

Millions

(Unaudited)

	Common<br>Stock			Treasury<br>Stock			Retained<br>Earnings		Accumulated<br>Other<br>Comprehensive<br>Income (Loss)
	Shs.	Amount		Shs.	Amount			Total
Balance as of March 31, 2021	534	$	5,013	(30)	$	(902)	$	12,708	$	(542)	$	16,277
Net Loss	—	—		—	—		(177)		—		(177)
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(12)	—	—		—	—		—		20		20
Comprehensive Loss											(157)
Cash Dividends at $0.51 per share on Common Stock	—	—		—	—		(258)		—		(258)
Other	—	13		—	3		—		—		16
Balance as of June 30, 2021	534	$	5,026	(30)	$	(899)	$	12,273	$	(522)	$	15,878
Balance as of March 31, 2020	534	$	4,994	(30)	$	(868)	$	11,604	$	(481)	$	15,249
Net Income	—	—		—	—		451		—		451
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(14)	—	—		—	—		—		26		26
Comprehensive Income											477
Cash Dividends at $0.49 per share on Common Stock	—	—		—	—		(247)		—		(247)
Other	—	9		—	3		—		—		12
Balance as of June 30, 2020	534	$	5,003	(30)	$	(865)	$	11,808	$	(455)	$	15,491			Common<br>Stock			Treasury<br>Stock			Retained<br>Earnings		Accumulated<br>Other<br>Comprehensive<br>Income (Loss)
---	---	---	---	---	---	---	---	---	---	---	---	---
	Shs.	Amount		Shs.	Amount			Total
Balance as of December 31, 2020	534	$	5,031	(30)	$	(861)	$	12,318	$	(504)	$	15,984
Net Income	—	—		—	—		471		—		471
Other Comprehensive Income (Loss), net of tax (expense) benefit of $12	—	—		—	—		—		(18)		(18)
Comprehensive Income											453
Cash Dividends at $1.02 per share on Common Stock	—	—		—	—		(516)		—		(516)
Other	—	(5)		—	(38)		—		—		(43)
Balance as of June 30, 2021	534	$	5,026	(30)	$	(899)	$	12,273	$	(522)	$	15,878
Balance as of December 31, 2019	534	$	5,003	(30)	$	(831)	$	11,406	$	(489)	$	15,089
Net Income	—	—		—	—		899		—		899
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(20)	—	—		—	—		—		34		34
Comprehensive Income											933
Cumulative Effect Adjustment for Current Expected Credit Losses (CECL)	—	—		—	—		(2)		—		(2)
Cash Dividends at $0.98 per share on Common Stock	—	—		—	—		(495)		—		(495)
Other	—	—		—	(34)		—		—		(34)
Balance as of June 30, 2020	534	$	5,003	(30)	$	(865)	$	11,808	$	(455)	$	15,491

See Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ELECTRIC AND GAS COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

Millions

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
OPERATING REVENUES	$	1,514	$	1,456	$	3,587	$	3,339
OPERATING EXPENSES
Energy Costs	509		510		1,358		1,218
Operation and Maintenance	393		380		817		766
Depreciation and Amortization	231		217		472		439
Total Operating Expenses	1,133		1,107		2,647		2,423
OPERATING INCOME	381		349		940		916
Net Gains (Losses) on Trust Investments	—		1		1		1
Other Income (Deductions)	24		26		52		53
Net Non-Operating Pension and OPEB Credits (Costs)	66		52		132		103
Interest Expense	(101)		(98)		(199)		(194)
INCOME BEFORE INCOME TAXES	370		330		926		879
Income Tax Benefit (Expense)	(61)		(47)		(140)		(156)
NET INCOME	$	309	$	283	$	786	$	723

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ELECTRIC AND GAS COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

Millions

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
NET INCOME	$	309	$	283	$	786	$	723
Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit of $0, $(1), $1 and $(1) for the three and six months ended 2021 and 2020, respectively	1		1		(2)		1
COMPREHENSIVE INCOME	$	310	$	284	$	784	$	724

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ELECTRIC AND GAS COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

Millions

(Unaudited)

	June 30,<br>2021		December 31,<br>2020
ASSETS
CURRENT ASSETS
Cash and Cash Equivalents	$	40	$	204
Accounts Receivable, net of allowance of $251 in 2021 and $196 in 2020	991		1,004
Unbilled Revenues, net of allowance of $9 in 2021 and $10 in 2020	207		229
Materials and Supplies, net	227		217
Prepayments	204		14
Regulatory Assets	321		369
Other	28		13
Total Current Assets	2,018		2,050
PROPERTY, PLANT AND EQUIPMENT	37,357		36,300
Less: Accumulated Depreciation and Amortization	(7,389)		(7,149)
Net Property, Plant and Equipment	29,968		29,151
NONCURRENT ASSETS
Regulatory Assets	3,945		3,872
Operating Lease Right-of-Use Assets	93		99
Long-Term Investments	202		222
Rabbi Trust Fund	44		51
Other	126		136
Total Noncurrent Assets	4,410		4,380
TOTAL ASSETS	$	36,396	$	35,581

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ELECTRIC AND GAS COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

Millions

(Unaudited)

	June 30,<br>2021		December 31,<br>2020
LIABILITIES AND CAPITALIZATION
CURRENT LIABILITIES
Long-Term Debt Due Within One Year	$	—	$	434
Commercial Paper and Loans	—		100
Accounts Payable	525		671
Accounts Payable—Affiliated Companies	300		479
Accrued Interest	104		101
Clean Energy Program	231		143
Obligation to Return Cash Collateral	101		98
Regulatory Liabilities	301		294
Other	437		530
Total Current Liabilities	1,999		2,850
NONCURRENT LIABILITIES
Deferred Income Taxes and ITC	4,716		4,524
Regulatory Liabilities	2,628		2,707
Operating Leases	83		88
Asset Retirement Obligations	316		314
OPEB Costs	476		485
Accrued Pension Costs	546		612
Environmental Costs	187		236
Long-Term Accrued Taxes	4		7
Other	158		154
Total Noncurrent Liabilities	9,114		9,127
COMMITMENTS AND CONTINGENT LIABILITIES (See Note 11)
CAPITALIZATION
LONG-TERM DEBT	11,370		10,475
STOCKHOLDER’S EQUITY
Common Stock; 150 shares authorized; issued and outstanding, 2021 and 2020—132 shares	892		892
Contributed Capital	1,170		1,170
Basis Adjustment	986		986
Retained Earnings	10,864		10,078
Accumulated Other Comprehensive Income	1		3
Total Stockholder’s Equity	13,913		13,129
Total Capitalization	25,283		23,604
TOTAL LIABILITIES AND CAPITALIZATION	$	36,396	$	35,581

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ELECTRIC AND GAS COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

Millions

(Unaudited)

	Six Months Ended
	June 30,
	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$	786	$	723
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	472		439
Provision for Deferred Income Taxes and ITC	63		74
Non-Cash Employee Benefit Plan (Credits) Costs	(78)		(51)
Cost of Removal	(60)		(44)
Net Change in Regulatory Assets and Liabilities	(24)		(70)
Net Change in Certain Current Assets and Liabilities:
Accounts Receivable and Unbilled Revenues	35		69
Materials and Supplies	(10)		1
Prepayments	(190)		(155)
Accounts Payable	(62)		39
Accounts Receivable/Payable—Affiliated Companies, net	(138)		(5)
Other Current Assets and Liabilities	(65)		40
Employee Benefit Plan Funding and Related Payments	(1)		—
Other	(48)		(61)
Net Cash Provided By (Used In) Operating Activities	680		999
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to Property, Plant and Equipment	(1,219)		(1,190)
Proceeds from Sales of Trust Investments	21		23
Purchases of Trust Investments	(15)		(22)
Solar Loan Investments	12		—
Other	7		7
Net Cash Provided By (Used In) Investing Activities	(1,194)		(1,182)
CASH FLOWS FROM FINANCING ACTIVITIES
Net Change in Commercial Paper and Loans	(100)		(362)
Issuance of Long-Term Debt	900		975
Redemption of Long-Term Debt	(434)		—
Cash Dividend Paid	—		(175)
Other	(8)		(11)
Net Cash Provided By (Used In) Financing Activities	358		427
Net Increase (Decrease) In Cash, Cash Equivalents and Restricted Cash	(156)		244
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	233		50
Cash, Cash Equivalents and Restricted Cash at End of Period	$	77	$	294
Supplemental Disclosure of Cash Flow Information:
Income Taxes Paid (Received)	$	150	$	51
Interest Paid, Net of Amounts Capitalized	$	190	$	179
Accrued Property, Plant and Equipment Expenditures	$	240	$	282

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PUBLIC SERVICE ELECTRIC AND GAS COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDER’S EQUITY

Millions

(Unaudited)

	Common Stock		Contributed Capital			Basis Adjustment		Retained Earnings		Accumulated<br>Other<br>Comprehensive<br>Income (Loss)
					Total
Balance as of March 31, 2021	$	892	$	1,170		$	986	$	10,555	$	—	$	13,603
Net Income	—		—			—		309		—		309
Other Comprehensive Income (Loss), net of tax (expense) benefit of $0	—		—			—		—		1		1
Comprehensive Income												310
Balance as of June 30, 2021	$	892	$	1,170		$	986	$	10,864	$	1	$	13,913
Balance as of March 31, 2020	$	892	$	1,095		$	986	$	9,191	$	2	$	12,166
Net Income	—		—			—		283		—		283
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(1)	—		—			—		—		1		1
Comprehensive Income												284
Balance as of June 30, 2020	$	892	$	1,095		$	986	$	9,474	$	3	$	12,450
	Common Stock		Contributed Capital			Basis Adjustment		Retained Earnings		Accumulated<br>Other<br>Comprehensive<br>Income (Loss)
---	---	---	---	---	---	---	---	---	---	---	---	---	---
					Total
Balance as of December 31, 2020	$	892	$	1,170		$	986	$	10,078	$	3	$	13,129
Net Income	—		—			—		786		—		786
Other Comprehensive Income (Loss), net of tax (expense) benefit of $1	—		—			—		—		(2)		(2)
Comprehensive Income												784
Balance as of June 30, 2021	$	892	$	1,170		$	986	$	10,864	$	1	$	13,913
Balance as of December 31, 2019	$	892	$	1,095		$	986	$	8,928	$	2	$	11,903
Net Income	—		—			—		723		—		723
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(1)	—		—			—		—		1		1
Comprehensive Income												724
Cumulative Effect Adjustment for CECL	—		—			—		(2)		—		(2)
Cash Dividend Paid	—		—			—		(175)		—		(175)
Balance as of June 30, 2020	$	892	$	1,095		$	986	$	9,474	$	3	$	12,450

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PSEG POWER LLC

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

Millions

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
OPERATING REVENUES	$	380	$	683	$	1,547	$	1,903
OPERATING EXPENSES
Energy Costs	271		323		953		999
Operation and Maintenance	259		225		481		466
Depreciation and Amortization	83		91		175		185
(Gains) Losses on Asset Dispositions and Impairments	457		—		457		—
Total Operating Expenses	1,070		639		2,066		1,650
OPERATING INCOME (LOSS)	(690)		44		(519)		253
Income from Equity Method Investments	6		3		9		6
Net Gains (Losses) on Trust Investments	79		196		137		(24)
Other Income (Deductions)	8		12		4		(11)
Net Non-Operating Pension and OPEB Credits (Costs)	11		9		23		17
Interest Expense	(24)		(30)		(51)		(64)
INCOME (LOSS) BEFORE INCOME TAXES	(610)		234		(397)		177
Income Tax Benefit (Expense)	127		(64)		75		6
NET INCOME (LOSS)	$	(483)	$	170	$	(322)	$	183

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PSEG POWER LLC

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

Millions

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
NET INCOME (LOSS)	$	(483)	$	170	$	(322)	$	183
Other Comprehensive Income (Loss), net of tax
Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit of $(8), $(12), $14 and $(16) for the three and six months ended 2021 and 2020, respectively	12		15		(20)		22
Pension/OPEB adjustment, net of tax (expense) benefit of $(1), $0, $(2) and $(1) for the three and six months ended 2021 and 2020, respectively	3		3		5		5
Other Comprehensive Income (Loss), net of tax	15		18		(15)		27
COMPREHENSIVE INCOME (LOSS)	$	(468)	$	188	$	(337)	$	210

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PSEG POWER LLC

CONDENSED CONSOLIDATED BALANCE SHEETS

Millions

(Unaudited)

	June 30,<br>2021		December 31,<br>2020
ASSETS
CURRENT ASSETS
Cash and Cash Equivalents	$	2	$	27
Accounts Receivable	367		328
Accounts Receivable—Affiliated Companies	165		317
Short-Term Loan to Affiliate	—		161
Fuel	207		277
Materials and Supplies, net	382		382
Prepayments	18		16
Derivative Contracts	35		60
Other	1		2
Total Current Assets	1,177		1,570
PROPERTY, PLANT AND EQUIPMENT	10,500		11,872
Less: Accumulated Depreciation and Amortization	(3,599)		(3,624)
Net Property, Plant and Equipment	6,901		8,248
NONCURRENT ASSETS
Operating Lease Right-of-Use Assets	23		61
NDT Fund	2,628		2,501
Long-Term Investments	67		64
Other Intangibles	122		158
Rabbi Trust Fund	64		66
Derivative Contracts	8		9
Other	41		27
Total Noncurrent Assets	2,953		2,886
TOTAL ASSETS	$	11,031	$	12,704

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PSEG POWER LLC

CONDENSED CONSOLIDATED BALANCE SHEETS

Millions

(Unaudited)

	June 30,<br>2021		December 31,<br>2020
LIABILITIES AND MEMBER’S EQUITY
CURRENT LIABILITIES
Long-Term Debt Due Within One Year	$	45	$	950
Accounts Payable	443		459
Accounts Payable—Affiliated Companies	199		13
Short-Term Loan from Affiliate	121		—
Derivative Contracts	34		21
Accrued Interest	11		16
Other	97		101
Total Current Liabilities	950		1,560
NONCURRENT LIABILITIES
Deferred Income Taxes and ITC	1,411		1,936
Operating Leases	13		51
Asset Retirement Obligations	951		895
OPEB Costs	197		197
Accrued Pension Costs	298		321
Derivative Contracts	6		4
Long-Term Accrued Taxes	64		57
Other	92		79
Total Noncurrent Liabilities	3,032		3,540
COMMITMENTS AND CONTINGENT LIABILITIES (See Note 11)
LONG-TERM DEBT	1,349		1,392
MEMBER’S EQUITY
Contributed Capital	2,310		2,310
Basis Adjustment	(986)		(986)
Retained Earnings	4,810		5,307
Accumulated Other Comprehensive Loss	(434)		(419)
Total Member’s Equity	5,700		6,212
TOTAL LIABILITIES AND MEMBER’S EQUITY	$	11,031	$	12,704

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PSEG POWER LLC

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

Millions

(Unaudited)

	Six Months Ended
	June 30,
	2021		2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	$	(322)	$	183
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from Operating Activities:
Depreciation and Amortization	175		185
Amortization of Nuclear Fuel	94		93
(Gains) Losses on Asset Dispositions and Impairments	457		—
Emission Allowances and REC Compliance Accrual	82		65
Provision for Deferred Income Taxes and ITC	(328)		7
Non-Cash Employee Benefit Plan (Credits) Costs	(10)		(3)
Interest Accretion on Asset Retirement Obligation	22		21
Net Realized and Unrealized (Gains) Losses on Energy Contracts and Other Derivatives	331		(1)
Net (Gains) Losses and (Income) Expense from NDT Fund	(158)		5
Net Change in Certain Current Assets and Liabilities:
Fuel, Materials and Supplies	68		70
Cash Collateral	(289)		32
Accounts Receivable	(10)		(14)
Accounts Payable	(39)		(92)
Accounts Receivable/Payable—Affiliated Companies, net	300		131
Other Current Assets and Liabilities	(11)		4
Employee Benefit Plan Funding and Related Payments	(4)		(3)
Other	(4)		(57)
Net Cash Provided By (Used In) Operating Activities	354		626
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to Property, Plant and Equipment	(82)		(218)
Purchase of Emission Allowances and RECs	(34)		(50)
Proceeds from Sales of Trust Investments	1,156		1,077
Purchases of Trust Investments	(1,163)		(1,100)
Proceeds from Sales of Long-Lived Assets	565		—
Short-Term Loan to Affiliate	161		45
Other	22		23
Net Cash Provided By (Used In) Investing Activities	625		(223)
CASH FLOWS FROM FINANCING ACTIVITIES
Cash Dividend Paid	(175)		—
Redemption of Long-Term Debt	(950)		(406)
Short-Term Loan from Affiliate	121		—
Other	—		(1)
Net Cash Provided By (Used In) Financing Activities	(1,004)		(407)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(25)		(4)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	27		21
Cash, Cash Equivalents and Restricted Cash at End of Period	$	2	$	17
Supplemental Disclosure of Cash Flow Information:
Income Taxes Paid (Received)	$	21	$	3
Interest Paid, Net of Amounts Capitalized	$	52	$	65
Accrued Property, Plant and Equipment Expenditures	$	69	$	49

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.

Table of Contents

PSEG POWER LLC

CONDENSED CONSOLIDATED STATEMENTS OF MEMBER’S EQUITY

Millions

(Unaudited)

	Contributed Capital		Basis Adjustment			Retained<br>Earnings		Accumulated<br>Other<br>Comprehensive<br>Income (Loss)
					Total
Balance as of March 31, 2021	$	2,310	$	(986)		$	5,293	$	(449)	$	6,168
Net Loss	—		—			(483)		—		(483)
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(9)	—		—			—		15		15
Comprehensive Loss										(468)
Balance as of June 30, 2021	$	2,310	$	(986)		$	4,810	$	(434)	$	5,700
Balance as of March 31, 2020	$	2,214	$	(986)		$	5,076	$	(392)	$	5,912
Net Income	—		—			170		—		170
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(12)	—		—			—		18		18
Comprehensive Income										188
Balance as of June 30, 2020	$	2,214	$	(986)		$	5,246	$	(374)	$	6,100			Contributed Capital		Basis Adjustment			Retained<br>Earnings		Accumulated<br>Other<br>Comprehensive<br>Income (Loss)
---	---	---	---	---	---	---	---	---	---	---	---
					Total
Balance as of December 31, 2020	$	2,310	$	(986)		$	5,307	$	(419)	$	6,212
Net Loss	—		—			(322)		—		(322)
Other Comprehensive Income (Loss), net of tax (expense) benefit of $12	—		—			—		(15)		(15)
Comprehensive Loss										(337)
Cash Dividends Paid	—		—			(175)		—		(175)
Balance as of June 30, 2021	$	2,310	$	(986)		$	4,810	$	(434)	$	5,700
Balance as of December 31, 2019	$	2,214	$	(986)		$	5,063	$	(401)	$	5,890
Net Income	—		—			183		—		183
Other Comprehensive Income (Loss), net of tax (expense) benefit of $(17)	—		—			—		27		27
Comprehensive Income										210
Balance as of June 30, 2020	$	2,214	$	(986)		$	5,246	$	(374)	$	6,100

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 1. Organization, Basis of Presentation and Significant Accounting Policies

Organization

Public Service Enterprise Group Incorporated (PSEG) is a holding company with a diversified business mix within the energy industry. Its operations are primarily in the Northeastern and Mid-Atlantic United States and in other select markets. PSEG’s principal direct wholly owned subsidiaries are:

•Public Service Electric and Gas Company (PSE&G)—which is a public utility engaged principally in the transmission of electricity and distribution of electricity and natural gas in certain areas of New Jersey. PSE&G is subject to regulation by the New Jersey Board of Public Utilities (BPU) and the Federal Energy Regulatory Commission (FERC). PSE&G also invests in regulated solar generation projects and energy efficiency and related programs in New Jersey, which are regulated by the BPU.

•PSEG Power LLC (PSEG Power)—which is a multi-regional energy supply company that integrates the operations of its merchant nuclear and fossil generating assets with its power marketing businesses and fuel supply functions through competitive energy sales in well-developed energy markets primarily in the Northeast and Mid-Atlantic United States through its principal direct wholly owned subsidiaries. PSEG Power’s subsidiaries are subject to regulation by FERC, the Nuclear Regulatory Commission (NRC), the Environmental Protection Agency (EPA) and the states in which they operate.

PSEG’s other direct wholly owned subsidiaries are: PSEG Long Island LLC (PSEG LI), which operates the Long Island Power Authority’s (LIPA) electric transmission and distribution (T&D) system under an Amended and Restated Operations Services Agreement (OSA); PSEG Energy Holdings L.L.C. (Energy Holdings), which earns it revenues from its portfolio of lease investments and holds our investment in offshore wind ventures; and PSEG Services Corporation (Services), which provides certain management, administrative and general services to PSEG and its subsidiaries at cost.

In December 2020, PSEG entered into a definitive agreement with Ørsted North America to acquire a 25% equity interest in Ørsted’s Ocean Wind project. Ocean Wind was selected by New Jersey to be the first offshore wind farm as part of the state’s intention to add 7,500 MW of offshore wind generating capacity by 2035. The Ocean Wind project is expected to achieve full commercial operation in 2025. On March 31, 2021, the BPU approved PSEG’s investment in Ocean Wind and the acquisition was completed in April 2021. Additionally, PSEG and Ørsted each owns 50% of Garden State Offshore Energy LLC which holds rights to an offshore wind lease area. PSEG and Ørsted are exploring other offshore wind opportunities.

Basis of Presentation

The respective financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC) applicable to Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting guidance generally accepted in the United States (GAAP) have been condensed or omitted pursuant to such rules and regulations. These Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements (Notes) should be read in conjunction with, and update and supplement matters discussed in, the Annual Report on Form 10-K for the year ended December 31, 2020.

The unaudited condensed consolidated financial information furnished herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal recurring nature. All significant intercompany accounts and transactions are eliminated in consolidation. The year-end Condensed Consolidated Balance Sheets were derived from the audited Consolidated Financial Statements included in the Annual Report on Form 10-K for the year ended December 31, 2020.

Significant Accounting Policies

Cash, Cash Equivalents and Restricted Cash

The following provides a reconciliation of cash, cash equivalents and restricted cash reported within the Condensed Consolidated Balance Sheets that sum to the total of the same such amounts for the beginning (December 31, 2020) and ending periods shown in the Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2021. Restricted cash consists primarily of deposits received related to various construction projects at PSE&G.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	PSE&G		PSEG Power		Other (A)		Consolidated
	Millions
As of December 31, 2020
Cash and Cash Equivalents	$	204	$	27	$	312	$	543
Restricted Cash in Other Current Assets	7		—		—		7
Restricted Cash in Other Noncurrent Assets	22		—		—		22
Cash, Cash Equivalents and Restricted Cash	$	233	$	27	$	312	$	572
As of June 30, 2021
Cash and Cash Equivalents	$	40	$	2	$	65	$	107
Restricted Cash in Other Current Assets	21		—		—		21
Restricted Cash in Other Noncurrent Assets	16		—		—		16
Cash, Cash Equivalents and Restricted Cash	$	77	$	2	$	65	$	144

(A)Includes amounts applicable to PSEG (parent company), Energy Holdings and Services.

Property, Plant and Equipment

PSEG Power capitalizes costs, including those related to its jointly-owned facilities that increase the capacity, improve or extend the life of an existing asset; represent a newly acquired or constructed asset; or represent the replacement of a retired asset. The cost of maintenance, repair and replacement of minor items of property is charged to appropriate expense accounts as incurred. Environmental costs are capitalized if the costs mitigate or prevent future environmental contamination or if the costs improve existing assets’ environmental safety or efficiency. All other environmental expenditures are expensed as incurred. PSEG Power also capitalizes spare parts that meet specific criteria. Capitalized spares are depreciated over the remaining lives of their associated assets.

In April 2021, the BPU awarded Zero Emission Certificates (ZECs) to PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants for an additional three years through May 2025. Concurrent with the BPU’s decision, PSEG Power reassessed the Asset Retirement Cost (ARC) and Asset Retirement Obligation (ARO) assumptions related to the Salem and Hope Creek units. This resulted in an increase to the ARC asset and ARO liability of $51 million, primarily due to lower discount rates and higher inflation. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments for additional information on ZECs.

Note 2. Recent Accounting Standards

New Standards Issued and Adopted

Simplifying the Accounting for Income Taxes—Accounting Standards Update (ASU) 2019-12

This accounting standard updates Accounting Standards Codification (ASC) 740 to simplify the accounting for income taxes, including the elimination of several exceptions and making other clarifications to the current guidance. Some of the more pertinent modifications include a change to the tax accounting related to franchise taxes that are partially based on income, an election to allocate the consolidated tax expense to a disregarded entity that is a member of a consolidated tax return filing group when those entities issue separate financial statements, and modifications and clarifications to interim tax reporting.

The standard is effective for fiscal years beginning after December 15, 2020. PSEG adopted this standard on January 1, 2021. PSEG has elected to allocate the consolidated tax expense to all eligible entities that are included in a consolidated tax filing on a prospective basis. This election is consistent with PSEG’s Tax Sharing Agreements with its affiliated subsidiaries. Adoption of this standard did not have an impact on the financial statements of PSEG, PSE&G, and PSEG Power.

Clarifying the Interactions between Investments-Equity Securities, Investments-Equity Method and Joint Ventures, and Derivatives and Hedging—ASU 2020-01

This accounting standard clarifies that an entity should consider transaction prices for purposes of measuring the fair value of certain equity securities immediately before applying or upon discontinuing the equity method. This accounting standard also clarifies that when accounting for contracts entered into to purchase equity securities, an entity should not consider whether, upon the settlement of the forward contract or exercise of the purchased option, the underlying securities would be accounted for under the equity method or the fair value option.

The standard is effective for fiscal years beginning after December 15, 2020. PSEG adopted this standard prospectively on

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

January 1, 2021. Adoption of this standard did not have an impact on the financial statements of PSEG, PSE&G and PSEG Power.

Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity—ASU 2020-06

This accounting standard simplifies the accounting for convertible debt and convertible preferred stock by removing the requirements to separately present certain conversion features in equity. In addition, the ASU eliminates certain criteria that must be satisfied in order to classify a contract as equity, which is expected to decrease the number of freestanding instruments and embedded derivatives accounted for as assets or liabilities. The ASU also revises the guidance on calculating earnings per share, requiring use of the if-converted method for all convertible instruments and rescinding the ability to rebut the presumption of share settlement for instruments that may be settled in cash or other assets.

The standard is effective for fiscal years beginning after December 15, 2021. PSEG early adopted this standard on January 1, 2021 on a modified retrospective basis. Adoption of this standard did not have an impact on the financial statements of PSEG, PSE&G and PSEG Power.

Codification Improvements to Callable Debt Securities—ASU 2020-08

This accounting standard clarifies that an entity should reevaluate for each reporting period whether a purchased callable debt security that has multiple call dates is within the scope of certain guidance on nonrefundable fees and other costs related to receivables.

The standard is effective for fiscal years beginning after December 15, 2020. PSEG adopted this standard prospectively on January 1, 2021. Adoption of this standard did not have an impact on the financial statements of PSEG, PSE&G and PSEG Power.

Codification Improvements—ASU 2020-10

This accounting standard conforms, clarifies, simplifies, and provides technical corrections to various codification topics.

The standard is effective for fiscal years beginning after December 15, 2020. PSEG adopted this standard on January 1, 2021. Adoption of this standard did not have an impact on the financial statements of PSEG, PSE&G and PSEG Power.

Reference Rate Reform Scope Refinement—ASU 2021-01

This accounting standard clarifies certain guidance related to derivative instruments affected by the market-wide change in the interest rates even if those derivatives do not reference the LIBOR or another rate that is expected to be discontinued as a result of reference rate reform. The accounting standard also clarifies other aspects of the relief provided in the reference rate reform GAAP guidance.

The standard is effective upon issuance and allows for retrospective or prospective application with certain conditions. PSEG adopted this standard prospectively in January 2021. Adoption of this standard did not have an impact on the financial statements of PSEG, PSE&G and PSEG Power.

New Standard Issued But Not Yet Adopted as of June 30, 2021

Issuer’s Accounting for Certain Modifications or Exchanges of Freestanding Equity-Classified Written Call Options—ASU 2021-04

This accounting standard clarifies an issuer’s accounting for certain modifications or exchanges of freestanding equity-classified written call options that remain equity-classified after modification or exchange. It provides guidance on how an issuer would determine whether it should recognize the modification or exchange as an adjustment to equity or an expense.

The standard is effective for fiscal years beginning after December 15, 2021 and early adoption is permitted. Amendments in this standard will be applied prospectively. PSEG is currently analyzing the impact of this standard on its financial statements.

Lessors-Certain Leases with Variable Lease Payments—ASU 2021-05

This accounting standard improves an area of the lease guidance related to a lessor’s accounting for certain leases with variable lease payments. It amends the lessor lease classification requirements and, as a result, a lessor is now required to classify and account for a lease with variable payments as an operating lease if (i) the lease would have been classified as a sales-type lease or a direct financing lease and (ii) the lessor would have otherwise recognized a day-one loss. A day-one loss or profit is not recognized under operating lease accounting.

The standard is effective for fiscal years beginning after December 15, 2021 and early adoption is permitted. Amendments in this standard will be applied either retrospectively or prospectively. PSEG is currently analyzing the impact of this standard on its financial statements.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 3. Revenues

Nature of Goods and Services

The following is a description of principal activities by reportable segment from which PSEG, PSE&G and PSEG Power generate their revenues.

PSE&G

Revenues from Contracts with Customers

Electric and Gas Distribution and Transmission Revenues—PSE&G sells gas and electricity to customers under default commodity supply tariffs. PSE&G’s regulated electric and gas default commodity supply and distribution services are separate tariffs which are satisfied as the product(s) and/or service(s) are delivered to the customer. The electric and gas commodity and delivery tariffs are recurring contracts in effect until modified through the regulatory approval process as appropriate. Revenue is recognized over time as the service is rendered to the customer. Included in PSE&G’s regulated revenues are unbilled electric and gas revenues which represent the estimated amount customers will be billed for services rendered from the most recent meter reading to the end of the respective accounting period.

PSE&G’s transmission revenues are earned under a separate tariff using a FERC-approved annual formula rate mechanism. The performance obligation of transmission service is satisfied and revenue is recognized as it is provided to the customer. The formula rate mechanism provides for an annual filing of an estimated revenue requirement with rates effective January 1 of each year and a true-up to that estimate based on actual revenue requirements. The true-up mechanism is an alternative revenue which is outside the scope of revenue from contracts with customers.

Other Revenues from Contracts with Customers

Other revenues from contracts with customers, which are not a material source of PSE&G revenues, are generated primarily from appliance repair services and solar generation projects. The performance obligations under these contracts are satisfied and revenue is recognized as control of products is delivered or services are rendered.

Payment for services rendered and products transferred are typically due on average within 30 days of delivery.

Revenues Unrelated to Contracts with Customers

Other PSE&G revenues unrelated to contracts with customers are derived from alternative revenue mechanisms recorded pursuant to regulatory accounting guidance. These revenues, which include the Conservation Incentive Program, weather normalization, green energy program true-ups and transmission formula rate true-ups, are not a material source of PSE&G revenues.

PSEG Power

Revenues from Contracts with Customers

Electricity and Related Products—Wholesale and retail load contracts are executed in the different Independent System Operator (ISO) regions for the bundled supply of energy, capacity, renewable energy credits (RECs) and ancillary services representing PSEG Power’s performance obligations. Revenue for these contracts is recognized over time as the bundled service is provided to the customer. Transaction terms generally run from several months to three years. PSEG Power also sells to the ISOs energy and ancillary services which are separately transacted in the day-ahead or real-time energy markets. The energy and ancillary services performance obligations are typically satisfied over time as delivered and revenue is recognized accordingly. PSEG Power generally reports electricity sales and purchases conducted with those individual ISOs net on an hourly basis in either Operating Revenues or Energy Costs in its Condensed Consolidated Statements of Operations. The classification depends on the net hourly activity.

PSEG Power enters into capacity sales and capacity purchases through the ISOs. The transactions are reported on a net basis dependent on PSEG Power’s monthly net sale or purchase position through the individual ISOs. The performance obligations with the ISOs are satisfied over time upon delivery of the capacity and revenue is recognized accordingly. In addition to capacity sold through the ISOs, PSEG Power sells capacity through bilateral contracts and the related revenue is reported on a gross basis and recognized over time upon delivery of the capacity.

In April 2019, PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs by the BPU. These nuclear plants are expected to receive ZEC revenue for approximately three years, through May 2022, from the electric distribution companies (EDCs) in New Jersey. In April 2021, PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs by the BPU for the three year eligibility period starting June 2022. PSEG Power recognizes revenue when the

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

units generate electricity, which is when the performance obligation is satisfied. These revenues are included in PJM Sales in the following tables. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments for additional information.

Gas Contracts—PSEG Power sells wholesale natural gas, primarily through an index based full-requirements Basic Gas Supply Service (BGSS) contract with PSE&G to meet the gas supply requirements of PSE&G’s customers. The BGSS contract remains in effect unless terminated by either party with a two-year notice. The performance obligation is primarily delivery of gas which is satisfied over time. Revenue is recognized as gas is delivered. Based upon the availability of natural gas, storage and pipeline capacity beyond PSE&G’s daily needs, PSEG Power also sells gas and pipeline capacity to other counterparties under bilateral contracts. The performance obligation under these contracts is satisfied over time upon delivery of the gas or capacity, and revenue is recognized accordingly.

Other Revenues from Contracts with Customers

Prior to the sale of PSEG Solar Source LLC (Solar Source), PSEG Power entered into bilateral contracts to sell solar power and solar RECs from its solar facilities. Contract terms ranged from 15 to 30 years. The performance obligations were generally solar power and RECs which were transferred to customers upon generation. Revenue was recognized upon generation of the solar power. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments.

PSEG Power has entered into long-term contracts with LIPA for energy management and fuel procurement services. Revenue is recognized over time as services are rendered.

Revenues Unrelated to Contracts with Customers

PSEG Power’s revenues unrelated to contracts with customers include electric, gas and certain energy-related transactions accounted for in accordance with Derivatives and Hedging accounting guidance. See Note 13. Financial Risk Management Activities for further discussion. Prior to the sale of Solar Source, PSEG Power was also a party to solar contracts that qualified as leases and were accounted for in accordance with lease accounting guidance. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments.

Other

Revenues from Contracts with Customers

PSEG LI has a contract with LIPA which generates revenues. PSEG LI’s subsidiary, Long Island Electric Utility Servco, LLC (Servco) records costs which are recovered from LIPA and records the recovery of those costs as revenues when Servco is a principal in the transaction.

Revenues Unrelated to Contracts with Customers

Energy Holdings generates lease revenues which are recorded pursuant to lease accounting guidance.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Disaggregation of Revenues

	PSE&G		PSEG Power		Other		Eliminations		Consolidated
	Millions
Three Months Ended June 30, 2021
Revenues from Contracts with Customers
Electric Distribution	$	765	$	—	$	—	$	—	$	765
Gas Distribution	256		—		—		(2)		254
Transmission	405		—		—		—		405
Electricity and Related Product Sales
PJM
Third-Party Sales	—		408		—		—		408
Sales to Affiliates	—		62		—		(62)		—
New York ISO	—		49		—		—		49
ISO New England	—		18		—		—		18
Gas Sales
Third-Party Sales	—		28		—		—		28
Sales to Affiliates	—		110		—		(110)		—
Other Revenues from Contracts with Customers (A)	81		12		145		(1)		237
Total Revenues from Contracts with Customers	1,507		687		145		(175)		2,164
Revenues Unrelated to Contracts with Customers (B)	7		(307)		10		—		(290)
Total Operating Revenues	$	1,514	$	380	$	155	$	(175)	$	1,874			PSE&G		PSEG Power		Other		Eliminations		Consolidated
---	---	---	---	---	---	---	---	---	---	---
	Millions
Six Months Ended June 30, 2021
Revenues from Contracts with Customers
Electric Distribution	$	1,472	$	—	$	—	$	—	$	1,472
Gas Distribution	1,152		—		—		(5)		1,147
Transmission	804		—		—		—		804
Electricity and Related Product Sales
PJM
Third-Party Sales	—		879		—		—		879
Sales to Affiliates	—		150		—		(150)		—
New York ISO	—		97		—		—		97
ISO New England	—		69		—		—		69
Gas Sales
Third-Party Sales	—		88		—		—		88
Sales to Affiliates	—		520		—		(520)		—
Other Revenues from Contracts with Customers (A)	156		22		286		(2)		462
Total Revenues from Contracts with Customers	3,584		1,825		286		(677)		5,018
Revenues Unrelated to Contracts with Customers (B)	3		(278)		20		—		(255)
Total Operating Revenues	$	3,587	$	1,547	$	306	$	(677)	$	4,763

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	PSE&G		PSEG Power		Other		Eliminations		Consolidated
	Millions
Three Months Ended June 30, 2020
Revenues from Contracts with Customers
Electric Distribution	$	723	$	—	$	—	$	—	$	723
Gas Distribution	278		—		—		(2)		276
Transmission	378		—		—		—		378
Electricity and Related Product Sales
PJM
Third-Party Sales	—		346		—		—		346
Sales to Affiliates	—		111		—		(111)		—
New York ISO	—		24		—		—		24
ISO New England	—		25		—		—		25
Gas Sales
Third-Party Sales	—		15		—		—		15
Sales to Affiliates	—		124		—		(124)		—
Other Revenues from Contracts with Customers (A)	83		14		141		—		238
Total Revenues from Contracts with Customers	1,462		659		141		(237)		2,025
Revenues Unrelated to Contracts with Customers (B)	(6)		24		7		—		25
Total Operating Revenues	$	1,456	$	683	$	148	$	(237)	$	2,050			PSE&G		PSEG Power		Other		Eliminations		Consolidated
---	---	---	---	---	---	---	---	---	---	---
	Millions
Six Months Ended June 30, 2020
Revenues from Contracts with Customers
Electric Distribution	$	1,372	$	—	$	—	$	—	$	1,372
Gas Distribution	1,009		—		—		(4)		1,005
Transmission	744		—		—		—		744
Electricity and Related Product Sales
PJM
Third-Party Sales	—		714		—		—		714
Sales to Affiliates	—		232		—		(232)		—
New York ISO	—		49		—		—		49
ISO New England	—		73		—		—		73
Gas Sales
Third-Party Sales	—		44		—		—		44
Sales to Affiliates	—		478		—		(478)		—
Other Revenues from Contracts with Customers (A)	165		24		285		(1)		473
Total Revenues from Contracts with Customers	3,290		1,614		285		(715)		4,474
Revenues Unrelated to Contracts with Customers (B)	49		289		19		—		357
Total Operating Revenues	$	3,339	$	1,903	$	304	$	(715)	$	4,831

(A)Includes primarily revenues from appliance repair services and the sale of solar renewable energy certificates (SRECs) at auction at PSE&G, solar power projects and energy management and fuel service contracts with LIPA at PSEG Power, and PSEG LI’s OSA with LIPA in Other.

(B)Includes primarily alternative revenues at PSE&G, derivative contracts and lease contracts at PSEG Power, and lease contracts in Other.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Contract Balances

PSE&G

PSE&G did not have any material contract balances (rights to consideration for services already provided or obligations to provide services in the future for consideration already received) as of June 30, 2021 and December 31, 2020. Substantially all of PSE&G’s accounts receivable and unbilled revenues result from contracts with customers that are priced at tariff rates. Allowances represented approximately 18% and 14% of accounts receivable (including unbilled revenues) as of June 30, 2021 and December 31, 2020, respectively.

Accounts Receivable—Allowance for Credit Losses

PSE&G’s accounts receivable, including unbilled revenues, is primarily comprised of utility customer receivables for the provision of electric and gas service and appliance services, and are reported in the balance sheet as gross outstanding amounts adjusted for an allowance for credit losses. The allowance for credit losses reflects PSE&G’s best estimate of losses on the account balances. The allowance is based on PSE&G’s projection of accounts receivable aging, historical experience, economic factors and other currently available evidence, including the estimated impact of the ongoing coronavirus pandemic (COVID-19) on the outstanding balances as of June 30, 2021. PSE&G’s electric bad debt expense is recoverable through its Societal Benefits Clause mechanism. As of June 30, 2021, PSE&G deferred incremental gas bad debt expense for future regulatory recovery due to the impact of the ongoing pandemic. See Note 6. Rate Filings for additional information.

The following provides a reconciliation of PSE&G’s allowance for credit losses for the three months and six months ended June 30, 2021 and 2020:

		Three Months Ended June 30, 2021
Balance as of March 31, 2021		$	239
Utility Customer and Other Accounts
	Provision	34
	Write-offs, net of Recoveries of $5 million	(13)
Balance as of June 30, 2021		$	260
		Six Months Ended June 30, 2021
Balance as of January 1, 2021		$	206
Utility Customer and Other Accounts
	Provision	78
	Write-offs, net of Recoveries of $7 million	(24)
Balance as of June 30, 2021		$	260				Three Months Ended June 30, 2020
---	---	---	---
Balance as of March 31, 2020		$	80
Utility Customer and Other Accounts
	Provision	45
	Write-offs, net of Recoveries of $1 million	(4)
Balance as of June 30, 2020		$	121
		Six Months Ended June 30, 2020
Balance as of January 1, 2020 (A)		$	68
Utility Customer and Other Accounts
	Provision	77
	Write-offs, net of Recoveries of $3 million	(24)
Balance as of June 30, 2020		$	121

(A)Includes an $8 million pre-tax increase upon adoption of ASU 2016-13.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

PSEG Power

PSEG Power generally collects consideration upon satisfaction of performance obligations, and therefore, PSEG Power had no material contract balances as of June 30, 2021 and December 31, 2020.

PSEG Power’s accounts receivable include amounts resulting from contracts with customers and other contracts which are out of scope of accounting guidance for revenues from contracts with customers. The majority of these accounts receivable are subject to master netting agreements. As a result, accounts receivable resulting from contracts with customers and receivables unrelated to contracts with customers are netted within Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets.

PSEG Power’s accounts receivable consist mainly of revenues from wholesale load contracts and capacity sales which are executed in the different ISO regions. PSEG Power also sells energy and ancillary services directly to ISOs and other counterparties. In the wholesale energy markets in which PSEG Power operates, payment for services rendered and products transferred are typically due within 30 days of delivery. As such, there is little credit risk associated with these receivables. PSEG Power did not record an allowance for credit losses for these receivables as of June 30, 2021 or December 31, 2020. PSEG Power monitors the status of its counterparties on an ongoing basis to assess whether there are any anticipated credit losses.

Other

PSEG LI did not have any material contract balances as of June 30, 2021 and December 31, 2020.

Remaining Performance Obligations under Fixed Consideration Contracts

PSEG Power and PSE&G primarily record revenues as allowed by the guidance, which states that if an entity has a right to consideration from a customer in an amount that corresponds directly with the value to the customer of the entity’s performance completed to date, the entity may recognize revenue in the amount to which the entity has a right to invoice. PSEG has future performance obligations under contracts with fixed consideration as follows:

PSEG Power

As previously stated, capacity transactions with ISOs are reported on a net basis dependent on PSEG Power’s monthly net sale or purchase position through the individual ISOs.

Capacity Revenues from the PJM Annual Base Residual and Incremental Auctions—The Base Residual Auction is generally conducted annually three years in advance of the operating period. The 2022/2023 auction was held in June 2021 and the 2023/2024 auction is expected to be held in December 2021. PSEG Power expects to realize the following average capacity prices resulting from the base and incremental auctions, including unit specific bilateral contracts for previously cleared capacity obligations.

Delivery Year	$ per MW-Day	MW Cleared
June 2021 to May 2022	$166	7,700
June 2022 to May 2023	$98	6,300

Capacity Payments from the ISO New England Forward Capacity Market (FCM)—The FCM Auction is conducted annually three years in advance of the operating period. The table below includes PSEG Power’s cleared capacity in the FCM Auction for the Bridgeport Harbor Station 5 (BH5), which cleared the 2019/2020 auction at $231/MW-day for seven years, and the retirement of Bridgeport Harbor Station 3 effective May 31, 2021. PSEG Power expects to realize the following average capacity prices for capacity obligations to be satisfied resulting from the FCM Auctions which have been completed through May 2025 and the seven-year rate lock for BH5 through May 2026:

Delivery Year	$ per MW-Day (A)	MW Cleared
June 2021 to May 2022	$192	950
June 2022 to May 2023	$179	950
June 2023 to May 2024	$152	930
June 2024 to May 2025	$158	950
June 2025 to May 2026	$231	480

(A)    Capacity cleared prices for BH5 through 2026 will be escalated based upon the Handy-Whitman Index. These adjustments are not included above.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Bilateral capacity contracts—Capacity obligations pursuant to contract terms through 2029 are anticipated to result in revenues totaling $138 million.

Other

The LIPA OSA is a 12-year services contract ending in 2025 with annual fixed and incentive components. The fixed fee for the provision of services thereunder in 2021 is $68 million and is updated each year based on the change in the Consumer Price Index. See Note 11. Commitments and Contingent Liabilities for additional information.

Note 4. Early Plant Retirements/Asset Dispositions and Impairments

Nuclear

In April 2019, PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs by the BPU. Pursuant to a process established by the BPU, ZECs are purchased from selected nuclear plants and recovered through a non-bypassable distribution charge in the amount of $0.004 per kilowatt-hour (KWh) used (which is equivalent to approximately $10 per megawatt hour (MWh) generated in payments to selected nuclear plants (ZEC payment)). Each nuclear plant is expected to receive ZEC revenue for approximately three years, through May 2022.

In April 2021, PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs for the three-year eligibility period starting June 2022 at the same approximate $10 per MWh received during the current ZEC period through May 2022 referenced above. As a result, each nuclear plant is expected to receive ZEC revenue for an additional three years starting June 2022. The terms and conditions of this April 2021 ZEC award are the same as the current ZEC period as discussed above.

The award of ZECs attaches certain obligations, including an obligation to repay the ZECs in the event that a plant ceases operations during the period that it was awarded ZECs, subject to certain exceptions specified in the ZEC legislation. PSEG Power has and will continue to recognize revenue monthly as the nuclear plants generate electricity and satisfy their performance obligations. Further, the ZEC payment may be adjusted by the BPU at any time to offset environmental or fuel diversity payments that a selected nuclear plant may receive from another source. For instance, the New Jersey Division of Rate Counsel (New Jersey Rate Counsel), in written comments filed with the BPU, has advocated for the BPU to offset market benefits resulting from New Jersey’s rejoining the Regional Greenhouse Gas Initiative from the ZEC payment. PSEG intends to vigorously defend against these arguments. Due to its preliminary nature, PSEG cannot predict the outcome of this matter.

The BPU’s April 2019 decision awarding ZECs through May 2022 and April 2021 decision awarding ZECs through May 2025 have been appealed by the New Jersey Rate Counsel (Rate Counsel). In May 2021, Rate Counsel filed an appeal with the New Jersey Appellate Division of the BPU’s April 2021 decision. In July 2021, the New Jersey Supreme Court denied the Rate Counsel’s petition for further appellate review of the BPU’s April 2019 decision. PSEG cannot predict the outcome of these matters.

In the event that (i) the ZEC program is overturned or is otherwise materially adversely modified through legal process; or (ii) any of the Salem 1, Salem 2 and Hope Creek plants is not sufficiently valued for its environmental, fuel diversity or resilience attributes in future periods and does not otherwise experience a material financial change that would remove the need for such attributes to be sufficiently valued, PSEG Power will take all necessary steps to cease to operate all of these plants. Alternatively, even with sufficient valuation of these attributes, if the financial condition of the plants is materially adversely impacted by changes in commodity prices, FERC’s changes to the capacity market construct (absent sufficient capacity revenues provided under a program approved by the BPU in accordance with a FERC-authorized capacity mechanism), or, in the case of the Salem nuclear plants, decisions by the EPA and state environmental regulators regarding the implementation of Section 316(b) of the Clean Water Act (CWA) and related state regulations, or other factors, PSEG Power will take all necessary steps to cease to operate all of these plants. Ceasing operations of these plants would result in a material adverse impact on PSEG’s and PSEG Power’s results of operations.

Non-Nuclear

In July 2020, PSEG announced that it is exploring strategic alternatives for PSEG Power’s non-nuclear generating fleet, which includes more than 6,750 MW of fossil generation located in New Jersey, Connecticut, New York and Maryland and, prior to the sale of Solar Source, included 467 MW Solar Source portfolio located in various states. PSEG intends to retain ownership of PSEG Power’s existing nuclear fleet.

In May 2021, PSEG Power Ventures LLC (Power Ventures), a direct wholly owned subsidiary of PSEG Power, entered into a purchase agreement with Quattro Solar, LLC, an affiliate of LS Power, relating to the sale by Power Ventures of 100% of its ownership interest in Solar Source including its related assets and liabilities. The transaction closed in June 2021. As a result of

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

the sale, PSEG Power recorded a pre-tax gain on sale of approximately $62 million, which is inclusive of the recognition of previously deferred unamortized investment tax credits (ITC) of $185 million, and income tax expense of approximately $63 million primarily due to the recapture of ITC on units that operated for less than five years. Any potential transactions involving PSEG Power’s fossil generation are expected to be completed either in the fourth quarter of 2021 or the first quarter of 2022.

As a result of the strategic review of PSEG Power’s non-nuclear generating assets, and the launch in the fourth quarter of 2020 of an associated marketing process for their potential disposition, PSEG Power has performed an impairment assessment of its PJM, NYISO and ISO-NE asset groupings, as of each quarter end. The assessments included probability weightings assigned to undiscounted cash flow scenarios of retaining the assets through the end of their estimated useful lives and a successful disposition of the non-nuclear assets. Estimates of cash flows associated with a sale scenario were based on management’s expectations of the fair value of such assets. The probability weighted aggregation of undiscounted cash flows for the PJM and NYISO asset groupings expected to result from the use and potential disposition of the asset groups exceeded their carrying value at the assessment dates. As such, it demonstrated that no impairment exists for these asset groupings and they continue to remain classified as held-for-use as of June 30, 2021. However, neither the ISO-NE asset grouping’s probability weighted aggregation of undiscounted cash flows nor its fair value exceeded its carrying value as of June 30, 2021. This demonstrated that an impairment existed and PSEG Power recorded a pre-tax charge in (Gains) Losses on Asset Dispositions and Impairments of approximately $519 million for the ISO-NE asset grouping which has remained classified as held-for-use as of June 30, 2021.

There is no assurance that the strategic review will result in a sale or other disposition of all or any portion of the fossil generation assets. Any transaction would be subject to market conditions and customary closing conditions, including the receipt of all required regulatory approvals. Management expects that a change to a held-for-sale classification from a held-for-use classification would result in a pre-tax loss of approximately $2.5 billion related to additional impairments on the fossil assets being sold and other related fossil common fixed assets, employee severance and retention costs, environmental remediation costs, and debt redemption costs, including a make-whole premium among other things, and excluding any potential impacts on employee pension and other postretirement plans. This potential approximation of loss is a preliminary estimate and may change materially depending upon the ongoing marketing process and the terms of a final agreement, if any, to dispose of these assets.

Note 5. Variable Interest Entities (VIEs)

VIE for which PSEG LI is the Primary Beneficiary

PSEG LI consolidates Servco, a marginally capitalized VIE, which was created for the purpose of operating LIPA’s T&D system in Long Island, New York as well as providing administrative support functions to LIPA. PSEG LI is the primary beneficiary of Servco because it directs the operations of Servco, the activity that most significantly impacts Servco’s economic performance and it has the obligation to absorb losses of Servco that could potentially be significant to Servco. Such losses would be immaterial to PSEG.

Pursuant to the OSA, Servco’s operating costs are paid entirely by LIPA, and therefore, PSEG LI’s risk is limited related to the activities of Servco. PSEG LI has no current obligation to provide direct financial support to Servco. In addition to payment of Servco’s operating costs as provided for in the OSA, PSEG LI receives an annual contract management fee. PSEG LI’s annual contractual management fee, in certain situations, could be partially offset by Servco’s annual storm costs not approved by the Federal Emergency Management Agency, limited contingent liabilities and penalties for failing to meet certain performance metrics.

For transactions in which Servco acts as principal and controls the services provided to LIPA, such as transactions with its employees for labor and labor-related activities, including pension and OPEB-related transactions, Servco records revenues and the related pass-through expenditures separately in Operating Revenues and Operation and Maintenance (O&M) Expense, respectively. Servco recorded $129 million and $125 million for the three months ended June 30, 2021 and 2020, respectively, and $252 million for each of the six months ended June 30, 2021 and 2020, of O&M costs, the full reimbursement of which was reflected in Operating Revenues. For transactions in which Servco acts as an agent for LIPA, it records revenues and the related expenses on a net basis, resulting in no impact on PSEG’s Condensed Consolidated Statement of Operations.

VIE for which PSEG is not the Primary Beneficiary

PSEG holds a 25% equity interest in Ocean Wind JV HoldCo, LLC (OWH), which holds the Ocean Wind project that is expected to achieve full commercial operation in 2025. For additional information, see Note 1. Organization, Basis of Presentation and Significant Accounting Policies. OWH is considered a VIE since its equity investments at risk are not sufficient to permit this entity to finance its activities without additional subordinated financial support. Since PSEG does not

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

have voting control or the power to direct the activities of OWH that most significantly impact its economic performance, PSEG has determined that it is not the primary beneficiary and therefore will account for this investment under the equity method of accounting. PSEG’s maximum exposure to loss is currently limited to the $91 million carrying amount of its investment in OWH as of June 30, 2021, which is included in Long-Term Investments on PSEG’s Condensed Consolidated Balance Sheet.

Note 6. Rate Filings

This Note should be read in conjunction with Note 7. Regulatory Assets and Liabilities to the Consolidated Financial Statements in the Annual Report on Form 10-K for the year ended December 31, 2020.

In addition to items previously reported in the Annual Report on Form 10-K, significant regulatory orders received and currently pending rate filings with FERC and the BPU are as follows:

BGSS—In March 2021, the BPU gave final approval to PSE&G’s request to maintain the current BGSS rate of 32 cents per therm which had been provisionally approved effective October 1, 2020.

In June 2021, PSE&G made its annual BGSS filing with the BPU requesting to maintain the current BGSS rate of 32 cents. If approved, the BGSS rate would remain in place beginning October 1, 2021. This matter is pending.

Community Solar Energy Pilot (CSEP) Program—In May 2021, PSE&G made its initial filing for recovery of costs related to the CSEP program. New Jersey’s Clean Energy Act provided for the establishment of a "Community Solar Energy Pilot Program” which permits electric customers to participate in a solar energy project that is remotely located from their properties but is within their electric public utility service territory. The program allows for a credit to the customer's utility bill equal to the electricity generated attributable to the customer's participation in the solar energy project. PSE&G’s filing proposes to recover an initial revenue requirement of $0.4 million associated with the CSEP Program as a new component of PSE&G’s existing electric Green Program Recovery Charge (GPRC). This matter is pending.

COVID-19 Deferral—PSE&G continues to make quarterly filings as required by the BPU and has recorded a Regulatory Asset as of June 30, 2021 of approximately $82 million for net incremental costs, including $42 million for incremental gas bad debt expense associated with customer accounts receivable, which PSE&G expects are probable of recovery under the BPU order. In July 2021, PSE&G, joined by other New Jersey gas distribution companies, made a filing with the BPU noting that the current deferral period, which ends on September 30, 2021, does not allow for proper consideration and inclusion of all incremental COVID-19 related expenses in the Regulatory Asset, and requesting that the Board extend the deferral period through the end of 2023. This matter is pending.

Energy Strong (ES) II—In April 2021, the BPU approved PSE&G’s filing for a $13 million revenue increase under this investment program, effective May 2021. This increase represents the return on and of ES II electric investments placed in service through January 2021.

GPRC—In June 2021, the BPU approved as final the GPRC rates approved by the Board on a provisional basis in January 2021. In July 2021, PSE&G filed its 2021 GPRC cost recovery petition requesting BPU approval to recover a $2 million increase in each of electric and gas base rates annual revenues. This matter is pending.

Gas System Modernization Program II (GSMP II)—In May 2021, the BPU approved PSE&G’s December 2020 cost recovery petition to recover in gas base rates an annual revenue increase of approximately $21 million effective June 1, 2021. This increase represents the return on and of GSMP II investments placed in service through February 2021.

In June 2021, PSE&G filed a GSMP II cost recovery petition seeking BPU approval to recover in gas base rates an estimated annual revenue increase of $34 million effective December 1, 2021. This increase represents the return on and of GSMP II investments expected to be in service through August 31, 2021. This request will be updated in September 2021 for actual costs.

Remediation Adjustment Charge (RAC)—In July 2021, the BPU approved PSE&G’s RAC 28 filing requesting recovery of approximately $35 million in net manufactured gas plant remediation expenditures incurred from August 1, 2019 through July 31, 2020.

Transmission Formula Rates—In June 2021, PSE&G filed its 2020 true-up adjustment pertaining to its transmission formula rates in effect for 2020. This filing resulted in an additional annual revenue requirement of $13 million more than the 2020

originally filed revenue.

In July 2021, PSE&G filed for FERC’s approval of a settlement agreement effective August 1, 2021 reached with the BPU Staff and the Rate Counsel with respect to the level of PSE&G’s base transmission return on equity (ROE) and other formula

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

rate matters. The settlement reduces PSE&G’s base ROE from 11.18% to 9.9% and provides that the settling parties will not seek changes to the transmission formula rate for three years. This matter is pending.

Weather Normalization Charge (WNC)—In June 2021, PSE&G filed its 2021-2022 WNC petition seeking to refund $2 million to customers over the 2020-2021 Winter Period. The overcollection will be refunded to PSE&G gas customers during the 2021-2022 Winter Period. This matter is pending.

Note 7. Leases

PSEG and its subsidiaries are both a lessor and a lessee in operating leases. As of June 30, 2021, PSEG and its subsidiaries were lessors for leases classified as operating leases or leveraged leases. See Note 8. Financing Receivables. There was no significant change in amounts reported in Note 8. Leases in the Annual Report on Form 10-K for the year ended December 31, 2020 for operating leases in which PSE&G and Services are lessees. As a result of completion of the sale of the Solar Source units in June 2021, PSEG Power’s Operating Lease Right-of-Use Assets and Operating Lease Liabilities were both reduced by $33 million. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments.

PSEG and its subsidiaries, as lessors, have lease agreements with lease and non-lease components, which are primarily related to generating facilities. Rental income from these leases is included in Operating Revenues.

PSEG Power

Prior to the sale of Solar Source, certain of PSEG Power’s sales agreements related to its solar generating plants qualified as operating leases. Lease income was based on solar energy generation; therefore, all rental income recorded under these leases was variable. PSEG Power has no remaining operating leases.

Other

Energy Holdings is the lessor in leveraged leases. See Note 8. Financing Receivables.

Energy Holdings is the lessor in two operating leases for domestic energy generation facilities with remaining terms through 2036, one of which has an optional renewal period.

The following is the operating lease income for PSEG Power and Energy Holdings for the three and six months ended June 30, 2021 and 2020:

	PSEG Power		Energy Holdings		Total
	Millions
Operating Lease Income
Three Months Ended June 30, 2021
Fixed Lease Income	$	—	$	6	$	6
Variable Lease Income	7		—		7
Total Operating Lease Income	$	7	$	6	$	13
Six Months Ended June 30, 2021
Fixed Lease Income	$	—	$	11	$	11
Variable Lease Income	12		—		12
Total Operating Lease Income	$	12	$	11	$	23
Three Months Ended June 30, 2020
Fixed Lease Income	$	—	$	3	$	3
Variable Lease Income	8		—		8
Total Operating Lease Income	$	8	$	3	$	11
Six Months Ended June 30, 2020
Fixed Lease Income	$	—	$	8	$	8
Variable Lease Income	13		—		13
Total Operating Lease Income	$	13	$	8	$	21

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 8. Financing Receivables

PSE&G

PSE&G’s Solar Loan Programs are designed to help finance the installation of solar power systems throughout its electric service area. Interest income on the loans is recorded on an accrual basis. The loans are paid back with SRECs generated from the related installed solar electric system. PSE&G uses collection experience as a credit quality indicator for its Solar Loan Programs and conducts a comprehensive credit review for all prospective borrowers. As of June 30, 2021, none of the solar loans were impaired; however, in the event of a loan default or if a loan becomes impaired, the basis of the solar loan would be recovered through a regulatory recovery mechanism. As of June 30, 2021, none of the solar loans were delinquent and no loans are currently expected to become delinquent in light of the payment mechanism. Therefore, no current credit losses have been recorded for Solar Loan Programs I, II and III. A substantial portion of these amounts are noncurrent and reported in Long-Term Investments on PSEG’s and PSE&G’s Condensed Consolidated Balance Sheets. The following table reflects the outstanding loans by class of customer, none of which would be considered “non-performing.”

	As of
Outstanding Loans by Class of Customers	June 30,<br>2021		December 31,<br>2020
	Millions
Commercial/Industrial	$	133	$	145
Residential	5		6
Total	138		151
Current Portion (included in Accounts Receivable)	(30)		(29)
Noncurrent Portion (included in Long-Term Investments)	$	108	$	122

The solar loans originated under three Solar Loan Programs are comprised as follows:

Programs	Balance as of June 30, 2021		Funding Provided	Residential Loan Term	Non-Residential Loan Term
	Millions
Solar Loan I	$	17	prior to 2013	10 years	15 years
Solar Loan II	64		prior to 2015	10 years	15 years
Solar Loan III	57		largely funded as of June 30, 2021	10 years	10 years
Total	$	138

The average life of loans paid in full is eight years, which is lower than the loan terms of 10 to 15 years due to the generation of SRECs being greater than expected and/or cash payments made to the loan. Payments on all outstanding loans were current as of June 30, 2021 and have an average remaining life of approximately four years.

Energy Holdings

Energy Holdings, through several of its indirect subsidiaries, has investments in assets subject primarily to leveraged lease accounting. A leveraged lease is typically comprised of an investment by an equity investor and debt provided by a third-party debt investor. The debt is recourse only to the assets subject to lease and is not included on PSEG’s Condensed Consolidated Balance Sheets. As an equity investor, Energy Holdings’ equity investments in the leases are comprised of the total expected lease receivables over the lease terms plus the estimated residual values at the end of the lease terms, reduced for any income not yet earned on the leases. This amount is included in Long-Term Investments on PSEG’s Condensed Consolidated Balance Sheets. The more rapid depreciation of the leased property for tax purposes creates tax cash flow that will be repaid to the taxing authority in later periods. As such, the liability for such taxes due is recorded in Deferred Income Taxes on PSEG’s Condensed Consolidated Balance Sheets.

Leveraged leases outstanding as of June 30, 2021 commenced in or prior to 2000. The following table shows Energy Holdings’ gross and net lease investment as of June 30, 2021 and December 31, 2020.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	As of
	June 30,<br>2021		December 31,<br>2020
	Millions
Lease Receivables (net of Non-Recourse Debt)	$	274	$	299
Estimated Residual Value of Leased Assets	55		55
Total Investment in Rental Receivables	329		354
Unearned and Deferred Income	(96)		(104)
Gross Investments in Leases	233		250
Deferred Tax Liabilities	(57)		(64)
Net Investments in Leases	$	176	$	186

The corresponding receivables associated with the lease portfolio are reflected as follows, net of non-recourse debt. The ratings in the table represent the ratings of the entities providing payment assurance to Energy Holdings.

		Lease Receivables, Net of<br>Non-Recourse Debt
Counterparties' Standard & Poor's (S&P) Credit Rating as of June 30, 2021
	As of June 30, 2021
		Millions
AA		$	8
A-		51
BBB+ to BBB		178
BB+		37
Total		$	274

The “BB+” rating in the preceding table represents a lease receivable related to Merrill Creek Reservoir. Metropolitan Edison Company (a subsidiary of First Energy) is the lease counterparty. As of June 30, 2021, the gross investment in this lease was $24 million ($19 million, net of deferred taxes).

PSEG recorded no credit losses for the leveraged leases existing on June 30, 2021. Upon the occurrence of certain defaults, indirect subsidiaries of Energy Holdings would exercise their rights and seek recovery of their investment, potentially including stepping into the lease directly to protect their investments. While these actions could ultimately protect or mitigate the loss of value, they could require the use of significant capital and trigger certain material tax obligations which could, for certain leases, wholly or partially be mitigated by tax indemnification claims against the counterparty. A bankruptcy of a lessee would likely delay and potentially limit any efforts on the part of the lessors to assert their rights upon default and could delay the monetization of claims.

Note 9. Trust Investments

Nuclear Decommissioning Trust (NDT) Fund

PSEG Power maintains an external master NDT to fund its share of decommissioning costs for its five nuclear facilities upon their respective termination of operation. The trust contains two separate funds: a qualified fund and a non-qualified fund. Section 468A of the Internal Revenue Code limits the amount of money that can be contributed into a qualified fund. The funds are managed by third-party investment managers who operate under investment guidelines developed by PSEG Power.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The following tables show the fair values and gross unrealized gains and losses for the securities held in the NDT Fund.

	As of June 30, 2021
	Cost		Gross<br>Unrealized<br>Gains		Gross<br>Unrealized<br>Losses		Fair<br>Value
	Millions
Equity Securities
Domestic	$	483	$	330	$	—	$	813
International	338		134		(6)		466
Total Equity Securities	821		464		(6)		1,279
Available-for-Sale Debt Securities
Government	703		15		(6)		712
Corporate	613		25		(3)		635
Total Available-for-Sale Debt Securities	1,316		40		(9)		1,347
Total NDT Fund Investments (A)	$	2,137	$	504	$	(15)	$	2,626

(A)The NDT Fund Investments table excludes foreign currency of $2 million as of June 30, 2021, which is part of the NDT Fund.

	As of December 31, 2020
	Cost		Gross<br>Unrealized<br>Gains		Gross<br>Unrealized<br>Losses		Fair<br>Value
	Millions
Equity Securities
Domestic	$	519	$	305	$	(3)	$	821
International	388		152		(9)		531
Total Equity Securities	907		457		(12)		1,352
Available-for-Sale Debt Securities
Government	555		27		(1)		581
Corporate	528		39		(1)		566
Total Available-for-Sale Debt Securities	1,083		66		(2)		1,147
Total NDT Fund Investments (A)	$	1,990	$	523	$	(14)	$	2,499

(A)The NDT Fund Investments table excludes foreign currency of $2 million as of December 31, 2020, which is part of the NDT Fund.

Net unrealized gains (losses) on debt securities of $18 million (after-tax) were included in Accumulated Other Comprehensive Loss on PSEG’s and PSEG Power’s Condensed Consolidated Balance Sheets as of June 30, 2021. The portion of net unrealized gains (losses) recognized in the second quarter and first half of 2021 related to equity securities still held as of June 30, 2021 was $61 million and $86 million, respectively.

The amounts in the preceding tables do not include receivables and payables for NDT Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table.

	As of		As of
	June 30,<br>2021		December 31,<br>2020
	Millions
Accounts Receivable	$	19	$	11
Accounts Payable	$	36	$	12

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The following table shows the value of securities in the NDT Fund that have been in an unrealized loss position for less than and greater than 12 months.

	As of June 30, 2021								As of December 31, 2020
	Less Than 12<br>Months				Greater Than 12<br>Months				Less Than 12<br>Months				Greater Than 12<br>Months
	Fair<br>Value		Gross<br>Unrealized<br>Losses		Fair<br>Value		Gross<br>Unrealized<br>Losses		Fair<br>Value		Gross<br>Unrealized<br>Losses		Fair<br>Value		Gross<br>Unrealized<br>Losses
	Millions
Equity Securities (A)
Domestic	$	12	$	—	$	—	$	—	$	23	$	(2)	$	6	$	(1)
International	39		(4)		9		(2)		26		(2)		27		(7)
Total Equity Securities	51		(4)		9		(2)		49		(4)		33		(8)
Available-for-Sale Debt Securities
Government (B)	277		(6)		6		—		72		(1)		—		—
Corporate (C)	156		(3)		8		—		31		(1)		7		—
Total Available-for-Sale Debt Securities	433		(9)		14		—		103		(2)		7		—
NDT Trust Investments	$	484	$	(13)	$	23	$	(2)	$	152	$	(6)	$	40	$	(8)

(A)Equity Securities—Investments in marketable equity securities within the NDT Fund are primarily in common stocks within a broad range of industries and sectors. Unrealized gains and losses on these securities are recorded in Net Income.

(B)Debt Securities (Government)—Unrealized gains and losses on these securities are recorded in Accumulated Other Comprehensive Income (Loss). The unrealized losses on PSEG Power’s NDT investments in U.S. Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. PSEG Power also has investments in municipal bonds. It is not expected that these securities will settle for less than their amortized cost. PSEG Power does not intend to sell these securities nor will it be more-likely-than-not required to sell before recovery of their amortized cost. PSEG Power did not recognize credit losses for U.S. Treasury obligations and Federal Agency mortgage-backed securities because these investments are guaranteed by the U.S. government or an agency of the U.S. government. PSEG Power did not recognize credit losses for municipal bonds because they are primarily investment grade securities.

(C)Debt Securities (Corporate)—Unrealized gains and losses on these securities are recorded in Accumulated Other Comprehensive Income (Loss). Unrealized losses were due to market declines. It is not expected that these securities would settle for less than their amortized cost. PSEG Power does not intend to sell these securities nor will it be more-likely-than-not required to sell before recovery of their amortized cost. PSEG Power did not recognize credit losses for these corporate bonds because they are primarily investment grade securities.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The proceeds from the sales of and the net gains (losses) on securities in the NDT Fund were:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
	Millions
Proceeds from NDT Fund Sales (A)	$	538	$	493	$	1,135	$	1,048
Net Realized Gains (Losses) on NDT Fund
Gross Realized Gains	$	83	$	32	$	162	$	70
Gross Realized Losses	(23)		(20)		(38)		(54)
Net Realized Gains (Losses) on NDT Fund (B)	60		12		124		16
Unrealized Gains (Losses) on Equity Securities	20		182		13		(39)
Impairment of Available-for-Sale Debt Securities (C)	—		—		—		(3)
Net Gains (Losses) on NDT Fund Investments	$	80	$	194	$	137	$	(26)

(A)Includes activity in accounts related to the liquidation of funds being transitioned within the trust.

(B)The cost of these securities was determined on the basis of specific identification.

(C)PSEG Power recognized an impairment of available-for-sale debt securities in 2020. PSEG Power’s policy is to sell all securities that are rated below investment grade.

The NDT Fund debt securities held as of June 30, 2021 had the following maturities:

Time Frame	Fair Value
	Millions
Less than one year	$	35
1 - 5 years	344
6 - 10 years	252
11 - 15 years	86
16 - 20 years	97
Over 20 years	533
Total NDT Available-for-Sale Debt Securities	$	1,347

PSEG Power periodically assesses individual debt securities whose fair value is less than amortized cost to determine whether the investments are impaired. For these securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). Any subsequent recoveries of the noncredit loss component of the impairment would be recorded through Accumulated Other Comprehensive Income (Loss). Any subsequent recoveries of the credit loss component would be recognized through earnings. The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities.

Rabbi Trust

PSEG maintains certain unfunded nonqualified benefit plans to provide supplemental retirement and deferred compensation benefits to certain key employees. Certain assets related to these plans have been set aside in a grantor trust commonly known as a “Rabbi Trust.”

The following tables show the fair values, gross unrealized gains and losses and amortized cost basis for the securities held in the Rabbi Trust.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	As of June 30, 2021
	Cost		Gross<br>Unrealized<br>Gains		Gross<br>Unrealized<br>Losses		Fair<br>Value
	Millions
Domestic Equity Securities	$	15	$	11	$	—	$	26
Available-for-Sale Debt Securities
Government	99		3		(2)		100
Corporate	111		7		—		118
Total Available-for-Sale Debt Securities	210		10		(2)		218
Other Securities	1		—		—		1
Total Rabbi Trust Investments	$	226	$	21	$	(2)	$	245			As of December 31, 2020
---	---	---	---	---	---	---	---	---
	Cost		Gross<br>Unrealized<br>Gains		Gross<br>Unrealized<br>Losses		Fair<br>Value
	Millions
Domestic Equity Securities	$	21	$	10	$	—	$	31
Available-for-Sale Debt Securities
Government	94		6		—		100
Corporate	123		12		—		135
Total Available-for-Sale Debt Securities	217		18		—		235
Total Rabbi Trust Investments	$	238	$	28	$	—	$	266

Net unrealized gains (losses) on debt securities of $6 million (after-tax) were included in Accumulated Other Comprehensive Loss on PSEG’s Condensed Consolidated Balance Sheet as of June 30, 2021. The portion of net unrealized gains recognized during the second quarter related to equity securities still held as of June 30, 2021 was $1 million and was immaterial for the first half of 2021.

The amounts in the preceding tables do not include receivables and payables for Rabbi Trust Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table.

	As of		As of
	June 30,<br>2021		December 31,<br>2020
	Millions
Accounts Receivable	$	1	$	1
Accounts Payable	$	—	$	1

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The following table shows the value of securities in the Rabbi Trust Fund that have been in an unrealized loss position for less than 12 months and greater than 12 months.

	As of June 30, 2021								As of December 31, 2020
	Less Than 12<br>Months				Greater Than 12<br>Months				Less Than 12<br>Months				Greater Than 12<br>Months
	Fair<br>Value		Gross<br>Unrealized<br>Losses		Fair<br>Value		Gross<br>Unrealized<br>Losses		Fair<br>Value		Gross<br>Unrealized<br>Losses		Fair<br>Value		Gross<br>Unrealized<br>Losses
	Millions
Available-for-Sale Debt Securities
Government (A)	$	56	$	(2)	$	—	$	—	$	19	$	—	$	—	$	—
Corporate (B)	23		—		1		—		2		—		1		—
Total Available-for-Sale Debt Securities	79		(2)		1		—		21		—		1		—
Rabbi Trust Investments	$	79	$	(2)	$	1	$	—	$	21	$	—	$	1	$	—

(A)Debt Securities (Government)—Unrealized gains and losses on these securities are recorded in Accumulated Other Comprehensive Income (Loss). The unrealized losses on PSEG’s Rabbi Trust investments in U.S. Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. PSEG also has investments in municipal bonds. It is not expected that these securities will settle for less than their amortized cost. PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell before recovery of their amortized cost. PSEG did not recognize credit losses for U.S. Treasury obligations and Federal Agency mortgage-backed securities because these investments are guaranteed by the U.S. government or an agency of the U.S. government. PSEG did not recognize credit losses for municipal bonds because they are primarily investment grade securities.

(B)Debt Securities (Corporate)—Unrealized gains and losses on these securities are recorded in Accumulated Other Comprehensive Income (Loss). Unrealized losses were due to market declines. It is not expected that these securities would settle for less than their amortized cost. PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell before recovery of their amortized cost. PSEG did not recognize credit losses for these corporate bonds because they are primarily investment grade.

The proceeds from the sales of and the net gains on securities in the Rabbi Trust Fund were:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
	Millions
Proceeds from Rabbi Trust Sales	$	29	$	61	$	94	$	115
Net Realized Gains (Losses) on Rabbi Trust:
Gross Realized Gains	$	2	$	5	$	7	$	10
Gross Realized Losses	(1)		(2)		(3)		(3)
Net Realized Gains (Losses) on Rabbi Trust (A)	1		3		4		7
Unrealized Gains (Losses) on Equity Securities	—		4		—		(1)
Net Gains (Losses) on Rabbi Trust Investments	$	1	$	7	$	4	$	6

(A)The cost of these securities was determined on the basis of specific identification.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The Rabbi Trust debt securities held as of June 30, 2021 had the following maturities:

Time Frame	Fair Value
	Millions
Less than one year	$	—
1 - 5 years	43
6 - 10 years	22
11 - 15 years	11
16 - 20 years	28
Over 20 years	114
Total Rabbi Trust Available-for-Sale Debt Securities	$	218

PSEG periodically assesses individual debt securities whose fair value is less than amortized cost to determine whether the investments are considered to be impaired. For these securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). Any subsequent recoveries of the noncredit loss component of the impairment would be recorded through Accumulated Other Comprehensive Income (Loss). Any subsequent recoveries of the credit loss component would be recognized through earnings. The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities.

The fair value of the Rabbi Trust related to PSE&G, PSEG Power and PSEG’s other subsidiaries is detailed as follows:

	As of		As of
	June 30,<br>2021		December 31,<br>2020
	Millions
PSE&G	$	44	$	51
PSEG Power	64		66
Other	137		149
Total Rabbi Trust Investments	$	245	$	266

Note 10. Pension and Other Postretirement Benefits (OPEB)

PSEG sponsors qualified and nonqualified pension plans and OPEB plans covering PSEG’s and its participating affiliates’ current and former employees who meet certain eligibility criteria.

PSEG, PSE&G and PSEG Power are required to record the under or over funded positions of their defined benefit pension and OPEB plans on their respective balance sheets. Such funding positions of each PSEG company are required to be measured as of the date of their respective year-end Consolidated Balance Sheets.

The following table provides the components of net periodic benefit credits relating to all qualified and nonqualified pension and OPEB plans on an aggregate basis for PSEG, excluding Servco. Amounts shown do not reflect the impacts of capitalization and co-owner allocations. Only the service cost component is eligible for capitalization, when applicable.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	Pension Benefits				OPEB				Pension Benefits				OPEB
	Three Months Ended				Three Months Ended				Six Months Ended				Six Months Ended
	June 30,				June 30,				June 30,				June 30,
	2021		2020		2021		2020		2021		2020		2021		2020
	Millions
Components of Net Periodic Benefit (Credits) Costs
Service Cost (included in O&M Expense)	$	38	$	35	$	2	$	3	$	76	$	70	$	4	$	5
Non-Service Components of Pension and OPEB (Credits) Costs
Interest Cost	35		48		6		8		70		96		11		17
Expected Return on Plan Assets	(119)		(110)		(11)		(9)		(238)		(221)		(21)		(19)
Amortization of Net
Prior Service Credit	—		(3)		(32)		(32)		—		(5)		(64)		(64)
Actuarial Loss	25		23		11		11		51		46		22		23
Non-Service Components of Pension and OPEB (Credits) Costs	(59)		(42)		(26)		(22)		(117)		(84)		(52)		(43)
Total Benefit (Credits) Costs	$	(21)	$	(7)	$	(24)	$	(19)	$	(41)	$	(14)	$	(48)	$	(38)

Pension and OPEB credits for PSE&G, PSEG Power and PSEG’s other subsidiaries, excluding Servco, are detailed as follows:

	Pension Benefits				OPEB				Pension Benefits				OPEB
	Three Months Ended				Three Months Ended				Six Months Ended				Six Months Ended
	June 30,				June 30,				June 30,				June 30,
	2021		2020		2021		2020		2021		2020		2021		2020
	Millions
PSE&G	$	(16)	$	(6)	$	(23)	$	(19)	$	(32)	$	(13)	$	(46)	$	(38)
PSEG Power	(5)		(2)		—		—		(9)		(3)		(1)		—
Other	—		1		(1)		—		—		2		(1)		—
Total Benefit (Credits) Costs	$	(21)	$	(7)	$	(24)	$	(19)	$	(41)	$	(14)	$	(48)	$	(38)

PSEG does not plan to contribute to its pension and OPEB plans in 2021.

Servco Pension and OPEB

At the direction of LIPA, Servco sponsors benefit plans that cover its current and former employees who meet certain eligibility criteria. Under the OSA, all of these and any future employee benefit costs are to be funded by LIPA. See Note 5. Variable Interest Entities. These obligations, as well as the offsetting long-term receivable, are separately presented on the Condensed Consolidated Balance Sheet of PSEG.

Servco amounts are not included in any of the preceding pension and OPEB cost disclosures. Pension and OPEB costs of Servco are accounted for according to the OSA. Servco recognizes expenses for contributions to its pension plan trusts and for OPEB payments made to retirees. Operating Revenues are recognized for the reimbursement of these costs. Servco plans to contribute $37 million into its pension plan during 2021. Servco’s pension-related revenues and costs were $10 million and $7 million for the three months ended June 30, 2021 and 2020, and $19 million and $15 million for the six months ended June 30, 2021 and 2020, respectively. The OPEB-related revenues earned and costs incurred were $2 million for each of the three months ended June 30, 2021 and 2020, and $5 million and $4 million for the six months ended June 30, 2021 and 2020, respectively.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 11. Commitments and Contingent Liabilities

Guaranteed Obligations

PSEG Power’s activities primarily involve the purchase and sale of energy and related products under transportation, physical, financial and forward contracts at fixed and variable prices. These transactions are with numerous counterparties and brokers that may require cash, cash-related instruments or guarantees as a form of collateral.

PSEG Power has unconditionally guaranteed payments to counterparties on behalf of its subsidiaries in commodity-related transactions in order to

•support current exposure, interest and other costs on sums due and payable in the ordinary course of business, and

•obtain credit.

PSEG Power is subject to

•counterparty collateral calls related to commodity contracts of its subsidiaries, and

•certain creditworthiness standards as guarantor under performance guarantees of its subsidiaries.

Under these agreements, guarantees cover lines of credit between entities and are often reciprocal in nature. The exposure between counterparties can move in either direction.

In order for PSEG Power to incur a liability for the face value of the outstanding guarantees,

•its subsidiaries would have to fully utilize the credit granted to them by every counterparty to whom PSEG Power has provided a guarantee, and

•the net position of the related contracts would have to be “out-of-the-money” (if the contracts are terminated, PSEG Power would owe money to the counterparties).

PSEG Power believes the probability of this result is unlikely. For this reason, PSEG Power believes that the current exposure at any point in time is a more meaningful representation of the potential liability under these guarantees. Current exposure consists of the net of accounts receivable and accounts payable and the forward value on open positions, less any collateral posted.

Changes in commodity prices can have a material impact on collateral requirements under such contracts, which are posted and received primarily in the form of cash and letters of credit. PSEG Power also routinely enters into futures and options transactions for electricity and natural gas as part of its operations. These futures contracts usually require a cash margin deposit with brokers, which can change based on market movement and in accordance with exchange rules.

In addition to the guarantees discussed above, PSEG Power has also provided payment guarantees to third parties and regulatory authorities on behalf of its affiliated companies. These guarantees support various other non-commodity related obligations.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The following table shows the face value of PSEG Power’s outstanding guarantees, current exposure and margin positions as of June 30, 2021 and December 31, 2020.

	As of		As of
	June 30, 2021		December 31, 2020
	Millions
Face Value of Outstanding Guarantees	$	1,830	$	1,792
Exposure under Current Guarantees	$	122	$	128
Letters of Credit Margin Posted	$	85	$	128
Letters of Credit Margin Received	$	28	$	45
Cash Deposited and Received
Counterparty Cash Collateral Deposited	$	5	$	—
Counterparty Cash Collateral Received	$	(1)	$	(5)
Net Broker Balance Deposited (Received)	$	339	$	59
Additional Amounts Posted
Other Letters of Credit	$	42	$	42

As part of determining credit exposure, PSEG Power nets receivables and payables with the corresponding net fair values of energy contracts. See Note 13. Financial Risk Management Activities for further discussion. In accordance with PSEG’s accounting policy, where it is applicable, cash (received)/deposited is allocated against derivative asset and liability positions with the same counterparty on the face of the Condensed Consolidated Balance Sheet. The remaining balances of net cash (received)/deposited after allocation are generally included in Accounts Payable and Receivable, respectively.

In addition to amounts for outstanding guarantees, current exposure and margin positions, PSEG and PSEG Power have posted letters of credit to support PSEG Power’s various other non-energy contractual and environmental obligations. See the preceding table.

Environmental Matters

Passaic River

Lower Passaic River Study Area

The U.S. Environmental Protection Agency (EPA) has determined that a 17-mile stretch of the Passaic River (Lower Passaic River Study Area (LPRSA)) in New Jersey is a “Superfund” site under the Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA). PSE&G and certain of its predecessors conducted operations at properties in this area, including at one site that was transferred to PSEG Power.

Certain Potentially Responsible Parties (PRPs), including PSE&G and PSEG Power, formed a Cooperating Parties Group (CPG) and agreed to conduct a Remedial Investigation and Feasibility Study of the LPRSA. The CPG allocated, on an interim basis, the associated costs among its members. The interim allocation is subject to change. In June 2019, the EPA conditionally approved the CPG’s Remedial Investigation. In December 2020, the EPA conditionally approved the CPG’s Feasibility Study (FS), which evaluated various adaptive management scenarios for the remediation of only the upper 9 miles of the LPRSA. In April 2021, the EPA announced the tentative selection of its preferred adaptive management scenario for the upper 9 miles from the options presented in the FS. A final selection is expected in the latter half of 2021.

Separately, the EPA has released a Record of Decision (ROD) for the LPRSA’s lower 8.3 miles that requires the removal of sediments at an estimated cost of $2.3 billion (ROD Remedy). An EPA-commenced process to allocate the associated costs is underway and PSEG cannot predict the outcome. The allocation does not address certain costs incurred by the EPA for which they may be entitled to reimbursement and which may be material. Occidental Chemical Corporation, one of the PRPs, has commenced the design of the ROD Remedy, but declined to participate in the allocation process. Instead, it filed suit against PSE&G and others seeking cost recovery and contribution under CERCLA but has not quantified alleged damages. The litigation is ongoing and PSEG cannot predict the outcome.

Two PRPs, Tierra Solutions, Inc. (Tierra) and Maxus Energy Corporation (Maxus), have filed for Chapter 11 bankruptcy. The trust representing the creditors in this proceeding has filed a complaint asserting claims against Tierra’s and Maxus’ current and former parent entities, among others. Any damages awarded may be used to fund the remediation of the LPRSA.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

As of June 30, 2021, PSEG has approximately $66 million accrued for this matter. Of this amount, PSE&G has an Environmental Costs Liability of $53 million and a corresponding Regulatory Asset based on its continued ability to recover such costs in its rates. PSEG Power has an Other Noncurrent Liability of $13 million.

The outcome of this matter is uncertain, and until (i) a final remedy for the entire LPRSA is selected and an agreement is reached by the PRPs to fund it, (ii) PSE&G’s and PSEG Power’s respective shares of the costs are determined, and (iii) PSE&G’s ability to recover the costs in its rates is determined, it is not possible to predict this matter’s ultimate impact on PSEG’s financial statements. It is possible that PSE&G and PSEG Power will record additional costs beyond what they have accrued, and that such costs could be material, but PSEG cannot at the current time estimate the amount or range of any additional costs.

Newark Bay Study Area

The EPA has established the Newark Bay Study Area, which is an extension of the LPRSA and includes Newark Bay and portions of surrounding waterways. The EPA has notified PSEG and 11 other PRPs of their potential liability. PSE&G and PSEG Power are unable to estimate their respective portions of any loss or possible range of loss related to this matter. In December 2018, PSEG Power completed the sale of the site of the Hudson electric generating station. PSEG Power contractually transferred all land rights and structures on the Hudson site to a third-party purchaser, along with the assumption of the environmental liabilities for the site.

Natural Resource Damage Claims

New Jersey and certain federal regulators have alleged that PSE&G, PSEG Power and 56 other PRPs may be liable for natural resource damages within the LPRSA. In particular, PSE&G, PSEG Power and other PRPs received notice from federal regulators of the regulators’ intent to move forward with a series of studies assessing potential damages to natural resources at the Diamond Alkali Superfund Site, which includes the LPRSA and the Newark Bay Study Area. PSE&G and PSEG Power are unable to estimate their respective portions of any possible loss or range of loss related to this matter.

Manufactured Gas Plant (MGP) Remediation Program

PSE&G is working with the New Jersey Department of Environmental Protection (NJDEP) to assess, investigate and remediate environmental conditions at its former MGP sites. To date, 38 sites requiring some level of remedial action have been identified. Based on its current studies, PSE&G has determined that the estimated cost to remediate all MGP sites to completion could range between $271 million and $309 million on an undiscounted basis, including its $53 million share for the Passaic River as discussed above. Since no amount within the range is considered to be most likely, PSE&G has recorded a liability of $271 million as of June 30, 2021. Of this amount, $89 million was recorded in Other Current Liabilities and $182 million was reflected as Environmental Costs in Noncurrent Liabilities. PSE&G has recorded a $271 million Regulatory Asset with respect to these costs. PSE&G periodically updates its studies taking into account any new regulations or new information which could impact future remediation costs and adjusts its recorded liability accordingly. PSE&G completed sampling in the Passaic River to delineate coal tar from certain MGP sites that abut the Passaic River Superfund site. PSEG cannot determine at this time the magnitude of any impact on the Passaic River Superfund remedy.

CWA Section 316(b) Rule

The EPA’s CWA Section 316(b) rule establishes requirements for the regulation of cooling water intakes at existing power plants and industrial facilities with a design flow of more than two million gallons of water per day. The EPA requires that National Pollutant Discharge Elimination System permits be renewed every five years and that each state Permitting Director manage renewal permits for its respective power generation facilities on a case by case basis. The NJDEP manages the permits under the New Jersey Pollutant Discharge Elimination System (NJPDES) program. Connecticut and New York also have permits to manage their respective pollutant discharge elimination system programs.

In June 2016, the NJDEP issued a final NJPDES permit for Salem. In July 2016, the Delaware Riverkeeper Network (Riverkeeper) filed an administrative hearing request challenging certain conditions of the permit, including the NJDEP’s application of the 316(b) rule. If the Riverkeeper’s challenge is successful, PSEG Power may be required to incur additional costs to comply with the CWA. Potential cooling water and/or service water system modification costs could be material and could adversely impact the economic competitiveness of this facility. The NJDEP granted the hearing request but no hearing date has been established.

Jersey City, New Jersey Subsurface Feeder Cable Matter

In October 2016, a discharge of dielectric fluid from subsurface feeder cables located in the Hudson River near Jersey City, New Jersey, was identified and reported to the NJDEP. The feeder cables are located within a subsurface easement granted to PSE&G by the property owners, Newport Associates Development Company (NADC) and Newport Associates Phase I

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Developer Limited Partnership. The feeder cables are subject to agreements between PSE&G and Consolidated Edison Company of New York, Inc. (Con Edison) and are jointly owned by PSE&G and Con Edison. The impacted cable was repaired in September 2017. A federal response was initially led by the U.S. Coast Guard. The U.S. Coast Guard transitioned control of the federal response to the EPA, and the EPA ended the federal response to the matter in 2018. The investigation of small amounts of residual dielectric fluid believed to be contained with the marina sediment is ongoing as part of the NJDEP site remediation program. In August 2020, PSE&G finalized a settlement with the federal government regarding the reimbursement of costs associated with the federal response to this matter and payment of civil penalties of an immaterial amount.

A lawsuit in federal court is pending to determine ultimate responsibility for the costs to address the leak among PSE&G, Con Edison and NADC. In addition, Con Edison filed counter claims against PSE&G and NADC, including seeking injunctive relief and damages. Based on the information currently available and depending on the outcome of the federal court action, PSE&G’s portion of the costs to address the leak may be material; however, PSE&G anticipates that it will recover its costs, other than civil penalties, through regulatory proceedings.

Basic Generation Service (BGS), BGSS and ZECs

Each year, PSE&G obtains its electric supply requirements through annual New Jersey BGS auctions for two categories of customers that choose not to purchase electric supply from third-party suppliers. The first category, which represents about 82% of PSE&G’s load requirement, is residential and smaller commercial and industrial customers (BGS-Residential Small Commercial Pricing (RSCP)). The second category is larger customers that exceed a BPU-established load (kW) threshold (BGS-Commercial and Industrial Energy Pricing (CIEP)). Pursuant to applicable BPU rules, PSE&G enters into the Supplier Master Agreements with the winners of these RSCP and CIEP BGS auctions to purchase BGS for PSE&G’s load requirements. The winners of the RSCP and CIEP auctions have been responsible for fulfilling all the requirements of a PJM load-serving entity including the provision of capacity, energy, ancillary services, transmission and any other services required by PJM. BGS suppliers assume all volume risk and customer migration risk and must satisfy New Jersey’s renewable portfolio standards. Beginning with the 2021 BGS auction, transmission became the responsibility of the New Jersey EDCs, and is no longer a component of the BGS auction product for either the RSCP or CIEP auctions. BGS suppliers serving load from the 2018, 2019 and 2020 BGS auctions had the option to transfer the transmission obligation to the New Jersey EDCs as of February 2021. Suppliers that did so have their total BGS payment from the EDCs reduced to reflect the transfer of the transmission obligation to the EDCs.

The BGS-CIEP auction is for a one-year supply period from June 1 to May 31 with the BGS-CIEP auction price measured in dollars per MW-day for capacity. The final price for the BGS-CIEP auction year commencing June 1, 2021 is $351.06 per MW-day, replacing the BGS-CIEP auction year price ending May 31, 2021 of $359.98 per MW-day. Energy for BGS-CIEP is priced at hourly PJM locational marginal prices for the contract period.

PSE&G contracts for its anticipated BGS-RSCP load on a three-year rolling basis, whereby each year one-third of the load is procured for a three-year period. The contract prices in dollars per MWh for the BGS-RSCP supply, as well as the approximate load, are as follows:

	Auction Year
	2018	2019	2020	2021
36-Month Terms Ending	May 2021	May 2022	May 2023	May 2024
Load (MW)	2,900	2,800	2,800	2,900
$ per MWh	$91.77	$98.04	$102.16	64.80

All values are in US Dollars.

(A)Prices set in the 2021 BGS auction became effective on June 1, 2021 when the 2018 BGS auction agreements expired.

PSE&G has a full-requirements contract with PSEG Power to meet the gas supply requirements of PSE&G’s gas customers. PSEG Power has entered into hedges for a portion of these anticipated BGSS obligations, as permitted by the BPU. The BPU permits PSE&G to recover the cost of gas hedging up to 115 billion cubic feet or 80% of its residential gas supply annual requirements through the BGSS tariff. Current plans call for PSEG Power to hedge on behalf of PSE&G approximately 70 billion cubic feet or 50% of its residential gas supply annual requirements. For additional information, see Note 20. Related-Party Transactions.

Pursuant to a process established by the BPU, New Jersey EDCs, including PSE&G, are required to purchase ZECs from eligible nuclear plants selected by the BPU. In April 2019, PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were selected to receive ZEC revenue for approximately three years, through May 2022. In April 2021, PSEG Power’s Salem 1,

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Salem 2 and Hope Creek nuclear plants were awarded ZECs for the three-year eligibility period starting June 2022. PSE&G has implemented a tariff to collect a non-bypassable distribution charge in the amount of $0.004 per KWh from its retail distribution customers to be used to purchase the ZECs from these plants. PSE&G will purchase the ZECs on a monthly basis with payment to be made annually following completion of each energy year. The legislation also requires nuclear plants to reapply for any subsequent three-year periods and allows the BPU to adjust prospective ZEC payments.

Minimum Fuel Purchase Requirements

PSEG Power’s nuclear fuel strategy is to maintain certain levels of uranium and to make periodic purchases to support such levels. As such, the commitments referred to in the following table may include estimated quantities to be purchased that deviate from contractual nominal quantities. PSEG Power’s nuclear fuel commitments cover approximately 100% of its estimated uranium, enrichment and fabrication requirements through 2022 and a significant portion through 2023 at Salem, Hope Creek and Peach Bottom.

PSEG Power has various multi-year contracts for natural gas and firm transportation and storage capacity for natural gas that are primarily used to meet its obligations to PSE&G. When there is excess delivery capacity available beyond the needs of PSE&G’s customers, PSEG Power can use the gas to supply its fossil generating stations in New Jersey.

As of June 30, 2021, the total minimum purchase requirements included in these commitments were as follows:

Fuel Type	PSEG Power’s Share of Commitments through 2025
	Millions
Nuclear Fuel
Uranium	$	194
Enrichment	$	314
Fabrication	$	170
Natural Gas	$	1,196

Pending FERC Matter

PSE&G has received subpoenas for information and a Notice of Investigation from FERC’s Office of Enforcement concerning the Roseland-Pleasant Valley transmission project. PSE&G is fully cooperating with FERC’s requests for information and the investigation. It is not possible at this time to predict the outcome of this matter.

Pending Tropical Storm Matter

Following the effects of Tropical Storm Isaias, the New York Attorney General initiated an inquiry into PSEG LI’s preparation and response to the storm. In addition, the Department of Public Service (DPS) within the New York State Public Service Commission launched an investigation of the state’s electric service providers’, including PSEG LI’s, preparation and response to the storm. The DPS issued an interim storm investigation report finding that PSEG LI violated its Emergency Response Plan and DPS Regulations, and recommended that LIPA consider taking various actions, including terminating or renegotiating the OSA. LIPA also issued a report with recommendations for improvements to PSEG LI’s structure and processes, and recommended that LIPA either renegotiate or terminate the OSA.

In agreement with LIPA, PSEG LI funded approximately $7 million in claims by customers for food and medication spoilage costs incurred as a result of being without electric service during the storm.

In December 2020, LIPA filed a complaint against PSEG LI in New York State court alleging multiple breaches of the OSA in connection with PSEG LI’s preparation for and response to Tropical Storm Isaias seeking specific performance and $70 million in damages. In June 2021, LIPA and PSEG LI executed a non-binding term sheet, which is expected to guide amendments to the OSA. The term sheet includes several changes to the OSA, including shifting a portion of PSEG LI’s fixed revenues to incentive compensation and subjecting a portion of revenue to the potential imposition of penalties by the DPS due to certain performance failures by PSEG LI, and resolves all of LIPA’s claims related to Tropical Storm Isaias and the DPS investigation. Any amendments to the OSA will require the approval of the New York Attorney General and the New York Comptroller. The OSA contract term will continue through 2025, with a mutual option to extend. No assurances can be given regarding reaching final settlement agreement, obtaining New York approvals and the closing of the inquiry by the Attorney General.

In the event that a final settlement with LIPA is not reached, PSEG LI intends to vigorously defend itself with regard to the allegations in LIPA’s complaint alleging breaches of the OSA. A decision in this proceeding requiring specific performance or

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

the payment of damages by PSEG LI or resulting in the termination of the OSA could have a material adverse effect on PSEG’s results of operations and financial condition.

Pending BPU Audit of PSE&G

In September 2020, the BPU ordered the commencement of a comprehensive affiliate and management audit of PSE&G. It has been more than ten years since the BPU last conducted a management and affiliate audit of this kind of PSE&G, which is initiated periodically as required by New Jersey statutes/regulations. Phase 1 of the planned audit will review affiliate relations and cost allocation between PSE&G and its affiliates, including an analysis of the relationship between PSE&G and PSEG Energy Resources & Trade, LLC, a wholly owned subsidiary of PSEG Power over the past ten years, and between PSE&G and PSEG LI. Phase 2 will be a comprehensive management audit, which will address, among other things, executive management, corporate governance, system operations, human resources, cyber security, compliance with customer protection requirements and customer safety. The audit officially began in late May 2021 and is in the data collection phase. It is not possible at this time to predict the outcome of this matter.

Litigation

Sewaren 7 Construction

In June 2018, a complaint was filed in federal court in Newark, New Jersey against PSEG Fossil LLC, a wholly owned subsidiary of PSEG Power, regarding an ongoing dispute with Durr Mechanical Construction, Inc. (Durr), a contractor on the Sewaren 7 project. Among other things, Durr seeks damages of $93 million and alleges that PSEG Power withheld money owed to Durr and that PSEG Power’s intentional conduct led to the inability of Durr to obtain prospective contracts. PSEG Power intends to vigorously defend against these allegations. In January 2021, the court partially granted PSEG Power’s motion to dismiss certain claims, reducing the amount claimed to $68 million. In December 2018, Durr filed for Chapter 11 bankruptcy in the federal court in the Southern District of New York (SDNY). The SDNY bankruptcy court has allowed the New Jersey litigation to proceed. PSEG Power has accrued an amount related to outstanding invoices which does not reflect an assessment of claims and potential counterclaims in this matter. Due to its preliminary nature, PSEG Power cannot predict the outcome of this matter.

Other Litigation and Legal Proceedings

PSEG and its subsidiaries are party to various lawsuits in the ordinary course of business. In view of the inherent difficulty in predicting the outcome of such matters, PSEG, PSE&G and PSEG Power generally cannot predict the eventual outcome of the pending matters, the timing of the ultimate resolution of these matters, or the eventual loss, fines or penalties related to each pending matter.

In accordance with applicable accounting guidance, a liability is accrued when those matters present loss contingencies that are both probable and reasonably estimable. In such cases, there may be an exposure to loss in excess of any amounts accrued. PSEG will continue to monitor the matter for further developments that could affect the amount of the accrued liability that has been previously established.

Based on current knowledge, management does not believe that loss contingencies arising from pending matters, other than the matters described herein, could have a material adverse effect on PSEG’s, PSE&G’s or PSEG Power’s consolidated financial position or liquidity. However, in light of the inherent uncertainties involved in these matters, some of which are beyond PSEG’s control, and the large or indeterminate damages sought in some of these matters, an adverse outcome in one or more of these matters could be material to PSEG’s, PSE&G’s or PSEG Power’s results of operations or liquidity for any particular reporting period.

Ongoing Coronavirus Pandemic

PSE&G, PSEG Power and PSEG LI are providing essential services during this national emergency related to the ongoing coronavirus (COVID-19) pandemic. The COVID-19 pandemic and associated government actions and economic effects continue to impact our businesses. PSEG and its subsidiaries have incurred additional expenses to protect our employees and customers, and PSE&G is experiencing significantly higher bad debts and lower cash collections from customers due to the moratorium on shutoffs for residential customers that has been extended through December 31, 2021. PSE&G has deferred the impact of these costs for future recovery. The potential future impact of the pandemic and the associated economic impacts, which could extend beyond the duration of the pandemic, could have risks that drive certain accounting considerations. The ultimate impact of the ongoing coronavirus pandemic is highly uncertain and cannot be predicted at this time.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 12. Debt and Credit Facilities

Long-Term Debt Financing Transactions

The following long-term debt transactions occurred in the six months ended June 30, 2021:

PSE&G

•issued $450 million of 0.95% Secured Medium-Term Notes, Series N, due March 2026,

•issued $450 million of 3.00% Secured Medium-Term Notes, Series N, due March 2051,

•retired $300 million of 1.90% Medium-Term Notes, Series K, at maturity, and

•retired $134 million of 9.25% Mortgage Bonds, Series CC, at maturity.

PSEG Power

•redeemed in May at par $700 million of 3.00% Senior Notes due to mature in June 2021, and

•redeemed in June at par $250 million of 4.15% Senior Notes due to mature in September 2021.

In August 2021, PSEG Power redeemed its $44 million of Pennsylvania Economic Development Financing Authority Variable Rate Bonds.

Debt Covenants

PSEG Power’s existing credit agreements and senior notes contain covenants restricting the ability of PSEG Power and its subsidiaries that guarantee its indebtedness from consummating certain mergers, consolidations or asset sales. The disposal of PSEG Power’s non-nuclear generating fleet could trigger a default under one or more of these provisions. For these reasons, or for other reasons, PSEG Power would expect to redeem its outstanding senior notes, at a price equal to the principal amount thereof plus a make-whole premium. Any actual redemption price would depend on the applicable treasury rate in effect at such time and the cost of such redemption would be material. In March 2021, PSEG Power and its subsidiaries received waivers from the lenders and the administrative agent under their existing credit agreements permitting them to divest, in one or more transactions, some or all of its and its subsidiaries’ non-nuclear assets without breaching the terms of the agreements.

Short-Term Liquidity

PSEG meets its short-term liquidity requirements, as well as those of PSEG Power, primarily through the issuance of commercial paper and, from time to time, short-term loans. PSE&G maintains its own separate commercial paper program to meet its short-term liquidity requirements. Each commercial paper program is fully back-stopped by its own separate credit facilities.

The commitments under the $4.2 billion credit facilities are provided by a diverse bank group. As of June 30, 2021, the total available credit capacity was $3.9 billion.

As of June 30, 2021, no single institution represented more than 9% of the total commitments in the credit facilities.

As of June 30, 2021, total credit capacity was in excess of the total anticipated maximum liquidity requirements over PSEG’s 12-month planning horizon, including access to external financing to meet redemptions.

Each of the credit facilities is restricted as to availability and use to the specific companies as listed in the following table; however, if necessary, the PSEG facilities can also be used to support its subsidiaries’ liquidity needs.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The total credit facilities and available liquidity as of June 30, 2021 were as follows:

	As of June 30, 2021
Company/Facility	Total<br>Facility		Usage (D)		Available<br>Liquidity		Expiration<br>Date	Primary Purpose
	Millions
PSEG
5-year Credit Facilities (A)	$	1,500	$	202	$	1,298	Mar 2024	Commercial Paper Support/Funding/Letters of Credit
Total PSEG	$	1,500	$	202	$	1,298
PSE&G
5-year Credit Facility (B)	$	600	$	18	$	582	Mar 2024	Commercial Paper Support/Funding/Letters of Credit
Total PSE&G	$	600	$	18	$	582
PSEG Power
3-year Letter of Credit Facility (E)	$	100	$	—	$	100	Sept 2021	Letters of Credit
3-year Letter of Credit Facility	100		86		14		Sept 2022	Letters of Credit
5-year Credit Facilities (C)	1,900		39		1,861		Mar 2024	Funding/Letters of Credit
Total PSEG Power	$	2,100	$	125	$	1,975
Total	$	4,200	$	345	$	3,855

(A)PSEG facilities will be reduced by $9 million in March 2022.

(B)PSE&G facility will be reduced by $4 million in March 2022.

(C)PSEG Power facilities will be reduced by $12 million in March 2022.

(D)The primary use of PSEG’s and PSE&G’s credit facilities is to support their respective Commercial Paper Programs, under which as of June 30, 2021, PSEG had $200 million outstanding at a weighted average interest rate of 0.23%. PSE&G had no Commercial Paper outstanding as of June 30, 2021.

(E)PSEG Power letter of credit facility was terminated in July 2021.

Short-Term Loans

PSEG

In May and March 2021, PSEG entered into two 364-day variable rate term loan agreements for $750 million and $500 million, respectively. In March 2020, PSEG entered into a $300 million, 364-day variable rate term loan agreement which was prepaid in January 2021.

Note 13. Financial Risk Management Activities

Derivative accounting guidance requires that a derivative instrument be recognized as either an asset or a liability at fair value, with changes in fair value of the derivative recognized in earnings each period. Other accounting treatments are available through special election and designation provided that the derivative instrument meets specific, restrictive criteria, both at the time of designation and on an ongoing basis. These alternative permissible treatments include normal purchases and normal sales (NPNS), cash flow hedge and fair value hedge accounting. PSEG, PSEG Power and PSE&G have applied the NPNS scope exception to certain derivative contracts for the forward sale of generation, power procurement agreements and fuel agreements. PSEG uses interest rate swaps and other derivatives, which are designated and qualifying as cash flow or fair value hedges. PSEG Power enters into additional contracts that are derivatives, but are not designated as either cash flow hedges or fair value hedges. These transactions are economic hedges and are recorded at fair market value with changes recognized in earnings.

Commodity Prices

Within PSEG and its affiliate companies, PSEG Power has the most exposure to commodity price risk. PSEG Power is exposed to commodity price risk primarily relating to changes in the market price of electricity, fossil fuels and other commodities. Fluctuations in market prices result from changes in supply and demand, fuel costs, market conditions, weather, state and federal regulatory policies, environmental policies, transmission availability and other factors. PSEG Power uses a variety of

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

derivative and non-derivative instruments, such as financial options, futures, swaps, fuel purchases and forward purchases and sales of electricity, to manage the exposure to fluctuations in commodity prices and optimize the value of PSEG Power’s expected generation. PSEG Power also uses derivatives to hedge a portion of its anticipated BGSS obligations with PSE&G. For additional information see Note 11. Commitments and Contingent Liabilities. Changes in the fair market value of these derivative contracts are recorded in earnings.

Interest Rates

PSEG, PSEG Power and PSE&G are subject to the risk of fluctuating interest rates in the normal course of business. Exposure to this risk is managed by targeting a balanced debt maturity profile which limits refinancing in any given period or interest rate environment. In addition, they have used a mix of fixed and floating rate debt and interest rate swaps.

Cash Flow Hedges

PSEG uses interest rate swaps and other derivatives, which are designated and effective as cash flow hedges, to manage its exposure to the variability of cash flows, primarily related to variable-rate debt instruments.

The Accumulated Other Comprehensive Income (Loss) (after tax) related to terminated interest rate derivatives designated as cash flow hedges was $(8) million and $(9) million as of June 30, 2021 and December 31, 2020, respectively. The after-tax unrealized losses on these hedges expected to be reclassified to earnings during the next 12 months are $(3) million.

Fair Values of Derivative Instruments

The following are the fair values of derivative instruments on the Condensed Consolidated Balance Sheets. The following tables also include disclosures for offsetting derivative assets and liabilities which are subject to a master netting or similar agreement. In general, the terms of the agreements provide that in the event of an early termination the counterparties have the right to offset amounts owed or owing under that and any other agreement with the same counterparty. Accordingly, and in accordance with PSEG’s accounting policy, these positions are offset on the Condensed Consolidated Balance Sheets of PSEG Power and PSEG. For additional information see Note 14. Fair Value Measurements. The following tabular disclosure does not include the offsetting of trade receivables and payables.

	As of June 30, 2021
	PSEG Power (A)						Consolidated
	Not Designated
Balance Sheet Location	Energy-<br>Related<br>Contracts		Netting<br>(B)		Total<br>PSEG Power		Total<br>Derivatives
	Millions
Derivative Contracts
Current Assets	$	682	$	(647)	$	35	$	35
Noncurrent Assets	247		(239)		8		8
Total Mark-to-Market Derivative Assets	$	929	$	(886)	$	43	$	43
Derivative Contracts
Current Liabilities	$	(882)	$	848	$	(34)	$	(34)
Noncurrent Liabilities	(313)		307		(6)		(6)
Total Mark-to-Market Derivative (Liabilities)	$	(1,195)	$	1,155	$	(40)	$	(40)
Total Net Mark-to-Market Derivative Assets (Liabilities)	$	(266)	$	269	$	3	$	3

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	As of December 31, 2020
	PSEG Power (A)						Consolidated
	Not Designated
Balance Sheet Location	Energy-<br>Related<br>Contracts		Netting<br>(B)		Total<br>PSEG Power		Total<br>Derivatives
	Millions
Derivative Contracts
Current Assets	$	464	$	(404)	$	60	$	60
Noncurrent Assets	93		(84)		9		9
Total Mark-to-Market Derivative Assets	$	557	$	(488)	$	69	$	69
Derivative Contracts
Current Liabilities	$	(412)	$	391	$	(21)	$	(21)
Noncurrent Liabilities	(109)		105		(4)		(4)
Total Mark-to-Market Derivative (Liabilities)	$	(521)	$	496	$	(25)	$	(25)
Total Net Mark-to-Market Derivative Assets (Liabilities)	$	36	$	8	$	44	$	44

(A)Substantially all of PSEG Power’s and PSEG’s derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of June 30, 2021 and December 31, 2020.

(B)Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral (received) posted that has been allocated to derivative positions, where the right of offset exists, has been offset on the Condensed Consolidated Balance Sheets. As of June 30, 2021 and December 31, 2020, PSEG Power had net cash collateral (receipts) payments to counterparties of $338 million and $54 million, respectively. Of these net cash collateral (receipts) payments, $269 million and $8 million as of June 30, 2021 and December 31, 2020, respectively, were netted against the corresponding net derivative contract positions. Of the $269 million as of June 30, 2021, $(7) million was netted against current assets, $(1) million was netted against noncurrent assets, $208 million was netted against current liabilities and $69 million was netted against noncurrent liabilities. Of the $8 million as of December 31, 2020, $(13) million was netted against current assets and $21 million was netted against noncurrent liabilities.

Certain of PSEG Power’s derivative instruments contain provisions that require PSEG Power to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon PSEG Power’s credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty. These credit risk-related contingent features stipulate that if PSEG Power were to be downgraded to a below investment grade rating by S&P or Moody’s, it would be required to provide additional collateral. A below investment grade credit rating for PSEG Power would represent a three level downgrade from its current Moody’s rating and a two level downgrade from its current S&P rating. This incremental collateral requirement can offset collateral requirements related to other derivative instruments that are assets with the same counterparty, where the contractual right of offset exists under applicable master agreements. PSEG Power also enters into commodity transactions on the New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE). The NYMEX and ICE clearing houses act as counterparties to each trade. Transactions on the NYMEX and ICE must adhere to comprehensive collateral and margin requirements.

The aggregate fair value of all derivative instruments with credit risk-related contingent features in a liability position that are not fully collateralized (excluding transactions on the NYMEX and ICE that are fully collateralized) was $45 million as of June 30, 2021 and $28 million as of December 31, 2020. As of June 30, 2021 and December 31, 2020, PSEG Power had the contractual right of offset of $6 million and $3 million, respectively, related to derivative instruments that are assets with the same counterparty under master agreements and net of margin posted. If PSEG Power had been downgraded to a below investment grade rating, it would have had additional collateral obligations of $39 million and $25 million as of June 30, 2021 and December 31, 2020, respectively, related to its derivatives, net of the contractual right of offset under master agreements and the application of collateral.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the three months and six months ended June 30, 2021 and 2020:

Derivatives in Cash Flow<br>Hedging Relationships		Amount of Pre-Tax<br>Gain (Loss)<br>Recognized in AOCI on Derivatives					Location of<br>Pre-Tax Gain (Loss) Reclassified from AOCI into Income		Amount of Pre-Tax<br>Gain (Loss)<br>Reclassified from AOCI into Income
	Three Months Ended							Three Months Ended
	June 30,							June 30,
	2021			2020				2021			2020
		Millions							Millions
PSEG
Interest Rate Swaps		$	—		$	—	Interest Expense		$	(1)		$	(4)
Total PSEG		$	—		$	—			$	(1)		$	(4)		Derivatives in Cash Flow<br>Hedging Relationships		Amount of Pre-Tax<br>Gain (Loss)<br>Recognized in AOCI on Derivatives					Location of<br>Pre-Tax Gain (Loss) Reclassified from AOCI into Income		Amount of Pre-Tax<br>Gain (Loss)<br>Reclassified from AOCI into Income
---	---	---	---	---	---	---	---	---	---	---	---	---	---
	Six Months Ended							Six Months Ended
	June 30,							June 30,
	2021			2020				2021			2020
		Millions							Millions
PSEG
Interest Rate Swaps		$	—		$	(6)	Interest Expense		$	(2)		$	(6)
Total PSEG		$	—		$	(6)			$	(2)		$	(6)

The effect of interest rate cash flow hedges is recorded in Interest Expense in PSEG’s Condensed Consolidated Statement of Operations. For the six months ended June 30, 2021, the amount of loss on interest rate hedges reclassified from Accumulated Other Comprehensive Income (Loss) into income was $(1) million after-tax. For the three months and six months ended June 30, 2020, the amount of loss on interest rate hedges reclassified from Accumulated Other Comprehensive Income (Loss) into income was $(3) million and $(4) million after-tax, respectively.

The following reconciles the Accumulated Other Comprehensive Income (Loss) for derivative activity included in the Accumulated Other Comprehensive Loss of PSEG on a pre-tax and after-tax basis.

Accumulated Other Comprehensive Income (Loss)	Pre-Tax		After-Tax
	Millions
Balance as of December 31, 2019	$	(21)	$	(15)
Loss Recognized in AOCI	(6)		(4)
Less: Loss Reclassified into Income	14		10
Balance as of December 31, 2020	$	(13)	$	(9)
Loss Recognized in AOCI	—		—
Less: Loss Reclassified into Income	2		1
Balance as of June 30, 2021	$	(11)	$	(8)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The following shows the effect on the Condensed Consolidated Statements of Operations of derivative instruments not designated as hedging instruments or as NPNS for the three months and six months ended June 30, 2021 and 2020, respectively. PSEG Power’s derivative contracts reflected in this table include contracts to hedge the purchase and sale of electricity and natural gas, and the purchase of fuel. The table does not include contracts that PSEG Power has designated as NPNS, such as its BGS contracts and certain other energy supply contracts that it has with other utilities and companies with retail load.

Derivatives Not Designated as Hedges	Location of Pre-Tax<br>Gain (Loss)<br>Recognized in Income<br>on Derivatives	Pre-Tax Gain (Loss) Recognized in Income on Derivatives
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2021		2020		2021		2020
		Millions
PSEG and PSEG Power
Energy-Related Contracts	Operating Revenues	$	(373)	$	(27)	$	(419)	$	204
Energy-Related Contracts	Energy Costs	75		2		81		(66)
Total PSEG and PSEG Power		$	(298)	$	(25)	$	(338)	$	138

The following table summarizes the net notional volume purchases/(sales) of open derivative transactions by commodity as of June 30, 2021 and December 31, 2020.

Type	Notional	Total	PSEG	PSEG Power	PSE&G
		Millions
As of June 30, 2021
Natural Gas	Dekatherm (Dth)	232	—	232	—
Electricity	MWh	(70)	—	(70)	—
Financial Transmission Rights (FTRs)	MWh	30	—	30	—
As of December 31, 2020
Natural Gas	Dth	321	—	321	—
Electricity	MWh	(66)	—	(66)	—
FTRs	MWh	20	—	20	—

Credit Risk

Credit risk relates to the risk of loss that PSEG Power would incur as a result of non-performance by counterparties pursuant to the terms of their contractual obligations. PSEG has established credit policies that it believes significantly minimize credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit rating), collateral requirements under certain circumstances and the use of standardized agreements, which allow for the netting of positive and negative exposures associated with a single counterparty. In the event of non-performance or non-payment by a major counterparty, there may be a material adverse impact on PSEG Power’s and PSEG’s financial condition, results of operations or net cash flows.

The following table provides information on PSEG Power’s credit risk from wholesale counterparties, net of collateral, as of June 30, 2021. It further delineates that exposure by the credit rating of the counterparties, which is determined by the lowest rating from S&P, Moody’s or an internal scoring model. In addition, it provides guidance on the concentration of credit risk to individual counterparties and an indication of the quality of PSEG Power’s credit risk by credit rating of the counterparties.

As of June 30, 2021, 99% of the net credit exposure for PSEG Power’s wholesale operations was with investment grade counterparties. Credit exposure is defined as any positive results of netting accounts receivable/accounts payable and the forward value of open positions (which includes all financial instruments including derivatives, NPNS and non-derivatives).

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Rating	Current<br>Exposure		Securities Held as Collateral		Net<br>Exposure		Number of<br>Counterparties<br>>10%	Net Exposure of<br>Counterparties<br>>10%
	Millions							Millions
Investment Grade	$	79	$	15	$	64	3	$	41	(A)
Non-Investment Grade	2		1		1		—	—
Total	$	81	$	16	$	65	3	$	41

(A)Represents net exposure of $21 million with PSE&G and $20 million with two non-affiliated counterparties.

As of June 30, 2021, collateral held from counterparties where PSEG Power had credit exposure included $16 million in letters of credit.

As of June 30, 2021, PSEG Power had 127 active counterparties.

PSE&G’s supplier master agreements are approved by the BPU and govern the terms of its electric supply procurement contracts. These agreements define a supplier’s performance assurance requirements and allow a supplier to meet its credit requirements with a certain amount of unsecured credit. The amount of unsecured credit is determined based on the supplier’s credit ratings from the major credit rating agencies and the supplier’s tangible net worth. The credit position is based on the initial market price, which is the forward price of energy on the day the procurement transaction is executed, compared to the forward price curve for energy on the valuation day. To the extent that the forward price curve for energy exceeds the initial market price, the supplier is required to post a parental guaranty or other security instrument such as a letter of credit or cash, as collateral to the extent the credit exposure is greater than the supplier’s unsecured credit limit. As of June 30, 2021, the posted collateral was principally in the form of parental guarantees. The unsecured credit used by the suppliers represents PSE&G’s net credit exposure. PSE&G’s BGS suppliers’ credit exposure is calculated each business day As of June 30, 2021, PSE&G had no net credit exposure with suppliers, including PSEG Power.

PSE&G is permitted to recover its costs of procuring energy through the BPU-approved BGS tariffs. PSE&G’s counterparty credit risk is mitigated by its ability to recover realized energy costs through customer rates.

Note 14. Fair Value Measurements

Fair value is the 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. Accounting guidance for fair value measurement emphasizes that fair value is a market-based measurement, not an entity-specific measurement, and establishes a fair value hierarchy that distinguishes between assumptions based on market data obtained from independent sources and those based on an entity’s own assumptions. The hierarchy prioritizes the inputs to fair value measurement into three levels:

Level 1—measurements utilize quoted prices (unadjusted) in active markets for identical assets or liabilities that PSEG, PSE&G and PSEG Power have the ability to access. These consist primarily of listed equity securities and money market mutual funds, as well as natural gas futures contracts executed on NYMEX.

Level 2—measurements include quoted prices for similar assets and liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, and other observable inputs such as interest rates and yield curves that are observable at commonly quoted intervals. These consist primarily of non-exchange traded derivatives such as forward contracts or options and most fixed income securities.

Level 3—measurements use unobservable inputs for assets or liabilities, based on the best information available and might include an entity’s own data and assumptions. In some valuations, the inputs used may fall into different levels of the hierarchy. In these cases, the financial instrument’s level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. These consist primarily of certain electric load contracts and gas contracts.

Certain derivative transactions may transfer from Level 2 to Level 3 if inputs become unobservable and internal modeling techniques are employed to determine fair value. Conversely, measurements may transfer from Level 3 to Level 2 if the inputs become observable.

The following tables present information about PSEG’s, PSE&G’s and PSEG Power’s respective assets and (liabilities) measured at fair value on a recurring basis as of June 30, 2021 and December 31, 2020, including the fair value measurements and the levels of inputs used in determining those fair values. Amounts shown for PSEG include the amounts shown for PSE&G and PSEG Power.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	Recurring Fair Value Measurements as of June 30, 2021
Description	Total		Netting (D)		Quoted Market Prices for Identical Assets<br>(Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	Millions
PSEG
Assets:
Cash Equivalents (A)	$	60	$	—	$	60	$	—	$	—
Derivative Contracts:
Energy-Related Contracts (B)	$	43	$	(886)	$	96	$	833	$	—
NDT Fund (C)
Equity Securities	$	1,279	$	—	$	1,279	$	—	$	—
Debt Securities—U.S. Treasury	$	326	$	—	$	—	$	326	$	—
Debt Securities—Govt Other	$	386	$	—	$	—	$	386	$	—
Debt Securities—Corporate	$	635	$	—	$	—	$	635	$	—
Rabbi Trust (C)
Equity Securities	$	26	$	—	$	26	$	—	$	—
Debt Securities—U.S. Treasury	$	66	$	—	$	—	$	66	$	—
Debt Securities—Govt Other	$	34	$	—	$	—	$	34	$	—
Debt Securities—Corporate	$	118	$	—	$	—	$	118	$	—
Other	$	1	$	—	$	—	$	1	$	—
Liabilities:
Derivative Contracts:
Energy-Related Contracts (B)	$	(40)	$	1,155	$	(55)	$	(1,132)	$	(8)
PSE&G
Assets:
Cash Equivalents (A)	$	30	$	—	$	30	$	—	$	—
Rabbi Trust (C)
Equity Securities	$	5	$	—	$	5	$	—	$	—
Debt Securities—U.S. Treasury	$	12	$	—	$	—	$	12	$	—
Debt Securities—Govt Other	$	6	$	—	$	—	$	6	$	—
Debt Securities—Corporate	$	21	$	—	$	—	$	21	$	—
PSEG Power
Assets:
Derivative Contracts:
Energy-Related Contracts (B)	$	43	$	(886)	$	96	$	833	$	—
NDT Fund (C)
Equity Securities	$	1,279	$	—	$	1,279	$	—	$	—
Debt Securities—U.S. Treasury	$	326	$	—	$	—	$	326	$	—
Debt Securities—Govt Other	$	386	$	—	$	—	$	386	$	—
Debt Securities—Corporate	$	635	$	—	$	—	$	635	$	—
Rabbi Trust (C)
Equity Securities	$	7	$	—	$	7	$	—	$	—
Debt Securities—U.S. Treasury	$	17	$	—	$	—	$	17	$	—
Debt Securities—Govt Other	$	9	$	—	$	—	$	9	$	—
Debt Securities—Corporate	$	31	$	—	$	—	$	31	$	—
Liabilities:
Derivative Contracts:
Energy-Related Contracts (B)	$	(40)	$	1,155	$	(55)	$	(1,132)	$	(8)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	Recurring Fair Value Measurements as of December 31, 2020
Description	Total		Netting  (D)		Quoted Market Prices for Identical Assets<br>(Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	Millions
PSEG
Assets:
Cash Equivalents (A)	$	312	$	—	$	312	$	—	$	—
Derivative Contracts:
Energy-Related Contracts (B)	$	69	$	(488)	$	26	$	519	$	12
NDT Fund (C)
Equity Securities	$	1,352	$	—	$	1,351	$	1	$	—
Debt Securities—U.S. Treasury	$	239	$	—	$	—	$	239	$	—
Debt Securities—Govt Other	$	342	$	—	$	—	$	342	$	—
Debt Securities—Corporate	$	566	$	—	$	—	$	566	$	—
Rabbi Trust (C)
Equity Securities	$	31	$	—	$	31	$	—	$	—
Debt Securities—U.S. Treasury	$	59	$	—	$	—	$	59	$	—
Debt Securities—Govt Other	$	41	$	—	$	—	$	41	$	—
Debt Securities—Corporate	$	135	$	—	$	—	$	135	$	—
Liabilities:
Derivative Contracts:
Energy-Related Contracts (B)	$	(25)	$	496	$	(33)	$	(483)	$	(5)
PSE&G
Assets:
Cash Equivalents (A)	$	50	$	—	$	50	$	—	$	—
Rabbi Trust (C)
Equity Securities	$	6	$	—	$	6	$	—	$	—
Debt Securities—U.S. Treasury	$	11	$	—	$	—	$	11	$	—
Debt Securities—Govt Other	$	8	$	—	$	—	$	8	$	—
Debt Securities—Corporate	$	26	$	—	$	—	$	26	$	—
PSEG Power
Assets:
Derivative Contracts:
Energy-Related Contracts (B)	$	69	$	(488)	$	26	$	519	$	12
NDT Fund (C)
Equity Securities	$	1,352	$	—	$	1,351	$	1	$	—
Debt Securities—U.S. Treasury	$	239	$	—	$	—	$	239	$	—
Debt Securities—Govt Other	$	342	$	—	$	—	$	342	$	—
Debt Securities—Corporate	$	566	$	—	$	—	$	566	$	—
Rabbi Trust (C)
Equity Securities	$	8	$	—	$	8	$	—	$	—
Debt Securities—U.S. Treasury	$	15	$	—	$	—	$	15	$	—
Debt Securities—Govt Other	$	10	$	—	$	—	$	10	$	—
Debt Securities—Corporate	$	33	$	—	$	—	$	33	$	—
Liabilities:
Derivative Contracts:
Energy-Related Contracts (B)	$	(25)	$	496	$	(33)	$	(483)	$	(5)

(A)Represents money market mutual funds.

(B)Level 1—These contracts represent natural gas futures contracts executed on NYMEX, and are being valued solely on settled pricing inputs which come directly from the exchange.

Level 2—Fair values for energy-related contracts are obtained primarily using a market-based approach. Most derivative contracts (forward purchase or sale contracts and swaps) are valued using settled prices from similar assets and liabilities from an exchange, such as NYMEX, ICE and Nodal Exchange, or auction prices. Prices used in

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

the valuation process are also corroborated independently by management to determine that values are based on actual transaction data or, in the absence of transactions, bid and offers for the day. Examples may include certain exchange and non-exchange traded capacity and electricity contracts and natural gas physical or swap contracts based on market prices, basis adjustments and other premiums where adjustments and premiums are not considered significant to the overall inputs.

Level 3—Unobservable inputs are used for the valuation of certain contracts. See “Additional Information Regarding Level 3 Measurements” below for more information on the utilization of unobservable inputs.

(C)The fair value measurement table excludes foreign currency of $2 million in the NDT Fund as of both June 30, 2021 and December 31, 2020. The NDT Fund maintains investments in various equity and fixed income securities. The Rabbi Trust maintains investments in a Russell 3000 index fund and various fixed income securities. These securities are generally valued with prices that are either exchange provided (equity securities) or market transactions for comparable securities and/or broker quotes (fixed income securities).

Level 1—Investments in marketable equity securities within the NDT Fund are primarily investments in common stocks across a broad range of industries and sectors. Most equity securities are priced utilizing the principal market close price or, in some cases, midpoint, bid or ask price. Certain other equity securities in the NDT and Rabbi Trust Funds consist primarily of investments in money market funds which seek a high level of current income as is consistent with the preservation of capital and the maintenance of liquidity. To pursue its goals, the funds normally invest in diversified portfolios of high quality, short-term, dollar-denominated debt securities and government securities. The funds’ net asset value is priced and published daily. The Rabbi Trust’s Russell 3000 index fund is valued based on quoted prices in an active market and can be redeemed daily without restriction.

Level 2—NDT and Rabbi Trust fixed income securities include investment grade corporate bonds, collateralized mortgage obligations, asset-backed securities and certain government and U.S. Treasury obligations or Federal Agency asset-backed securities and municipal bonds with a wide range of maturities. Since many fixed income securities do not trade on a daily basis, they are priced using an evaluated pricing methodology that varies by asset class and reflects observable market information such as the most recent exchange price or quoted bid for similar securities. Market-based standard inputs typically include benchmark yields, reported trades, broker/dealer quotes and issuer spreads. The preferred stocks are not actively traded on a daily basis and therefore, are also priced using an evaluated pricing methodology. Certain short-term investments are valued using observable market prices or market parameters such as time-to-maturity, coupon rate, quality rating and current yield.

(D)Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. See Note 13. Financial Risk Management Activities for additional detail.

Additional Information Regarding Level 3 Measurements

For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations for contracts with tenors that extend into periods with no observable pricing. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 because the model inputs generally are not observable. PSEG considers credit and non-performance risk in the valuation of derivative contracts categorized in Levels 2 and 3, including both historical and current market data, in its assessment of credit and non-performance risk by counterparty. The impacts of credit and non-performance risk were not material to the financial statements.

The fair value of PSEG Power’s electric load contracts in which load consumption may change hourly based on demand are measured using certain unobservable inputs, such as historic load variability and, accordingly, are categorized as Level 3. The fair value of PSEG Power’s gas physical contracts at certain illiquid delivery locations are measured using average historical basis and, accordingly, are categorized as Level 3. While these physical gas contracts have an unobservable component in their respective forward price curves, the fluctuations in fair value have been driven primarily by changes in the observable inputs.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

The following tables provide details surrounding significant Level 3 valuations as of June 30, 2021 and December 31, 2020.

	Quantitative Information About Level 3 Fair Value Measurements
							Significant
	Level 3	Fair Value as of				Valuation	Unobservable		Arithmetic
Commodity	Position	June 30, 2021				Technique(s)	Input	Range	Average
		Assets		(Liabilities)
		Millions
PSEG Power
Electricity	Electric Load Contracts	$	—	$	(6)	Discounted Cash Flow	Load Shaping Cost	0% to 11%	5%
Gas/Electric	Other (A)	—		(2)
Total PSEG Power		$	—	$	(8)
Total PSEG		$	—	$	(8)							Quantitative Information About Level 3 Fair Value Measurements
---	---	---	---	---	---	---	---	---	---
							Significant
	Level 3	Fair Value as of				Valuation	Unobservable		Arithmetic
Commodity	Position	December 31, 2020				Technique(s)	Input	Range	Average
		Assets		(Liabilities)
		Millions
PSEG Power
Electricity	Electric Load Contracts	$	12	$	—	Discounted Cash Flow	Load Shaping Cost	0% to 11%	4%
Gas	Gas Physical Contracts	—		(2)		Discounted Cash Flow	Historical Basis Adjustment	-60% to -30%	-43%
Electricity	Other (A)	—		(3)
Total PSEG Power		$	12	$	(5)
Total PSEG		$	12	$	(5)

(A)Other is comprised of primarily a heat rate call option and capacity swaps.

As of June 30, 2021, significant unobservable inputs listed above would have a direct impact on the fair values of the above Level 3 instruments if they were adjusted. For energy-related contracts in cases where PSEG Power is a seller, an increase in the load variability would decrease the fair value. For gas-related contracts in cases where PSEG Power is a buyer, an increase in the average historical basis would increase the fair value.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

A reconciliation of the beginning and ending balances of Level 3 derivative contracts and securities for the three months and six months ended June 30, 2021 and June 30, 2020, respectively, follows:

Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis

for the Three Months and Six Months Ended June 30, 2021

	Three Months Ended June 30, 2021
Description	Balance as of March 31, 2021		Total Gains or (Losses)<br>Realized/Unrealized Included in Income (A)		Purchases<br>(Sales)		Issuances/<br>Settlements<br>(B)		Transfers<br>In/Out (C)		Balance as of June 30, 2021
	Millions
PSEG and PSEG Power
Net Derivative Assets (Liabilities)	$	(1)	$	(9)	$	—	$	2	$	—	$	(8)
	Six Months Ended June 30, 2021
Description	Balance as of December 31, 2020		Total Gains or (Losses)<br>Realized/Unrealized Included in Income (A)		Purchases<br>(Sales)		Issuances/<br>Settlements<br>(B)		Transfers<br>In/Out (C)		Balance as of June 30, 2021
	Millions
PSEG and PSEG Power
Net Derivative Assets (Liabilities)	$	7	$	(13)	$	—	$	(2)	$	—	$	(8)

Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis

for the Three Months and Six Months Ended June 30, 2020

	Three Months Ended June 30, 2020
Description	Balance as of March 31, 2020		Total Gains or (Losses)<br>Realized/Unrealized Included in Income (A)		Purchases<br>(Sales)		Issuances/<br>Settlements<br>(B)		Transfers<br>In/Out<br>(C)		Balance as of June 30, 2020
	Millions
PSEG and PSEG Power
Net Derivative Assets (Liabilities)	$	19	$	(4)	$	—	$	(5)	$	—	$	10
	Six Months Ended June 30, 2020
Description	Balance as of December 31, 2019		Total Gains or (Losses)<br>Realized/Unrealized Included in Income (A)		Purchases<br>(Sales)		Issuances/<br>Settlements<br>(B)		Transfers<br>In/Out (C)		Balance as of June 30, 2020
	Millions
PSEG and PSEG Power
Net Derivative Assets (Liabilities)	$	7	$	9	$	—	$	(6)	$	—	$	10

(A)Unrealized gains (losses) in the following table represent the change in derivative assets and liabilities still held as of June 30, 2021 and 2020.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	Three Months Ended June 30,								Six Months Ended June 30,
	2021				2020				2021				2020
	Total Gains (Losses)		Unrealized Gains (Losses)		Total Gains (Losses)		Unrealized Gains (Losses)		Total Gains (Losses)		Unrealized Gains (Losses)		Total Gains (Losses)		Unrealized Gains (Losses)
	Millions
PSEG and PSEG Power
Operating Revenues	$	(7)	$	(7)	$	(4)	$	(9)	$	(12)	$	(16)	$	14	$	2
Energy Costs	(2)		(2)		—		—		(1)		(1)		(5)		1
Total	$	(9)	$	(9)	$	(4)	$	(9)	$	(13)	$	(17)	$	9	$	3

(B)Includes settlements of $2 million and $(2) million for the three months and six months ended June 30, 2021 and $(5) million and $(6) million for the three months and six months ended June 30, 2020.

(C)There were no transfers into or out of Level 3 during the three months and six months ended June 30, 2021 and 2020.

As of June 30, 2021, PSEG carried $2.9 billion of net assets that are measured at fair value on a recurring basis, of which $(8) million of net liabilities were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy were immaterial.

As of June 30, 2020, PSEG carried $2.9 billion of net assets that are measured at fair value on a recurring basis, of which $10 million of net assets was measured using unobservable inputs and classified as Level 3 within the fair value hierarchy.

Fair Value of Debt

The estimated fair values, carrying amounts and methods used to determine fair value of long-term debt as of June 30, 2021 and December 31, 2020 are included in the following table and accompanying notes.

	As of				As of
	June 30, 2021				December 31, 2020
	Carrying<br>Amount		Fair<br>Value		Carrying<br>Amount		Fair<br>Value
	Millions
Long-Term Debt:
PSEG (A)	$	2,931	$	3,031	$	2,929	$	3,092
PSE&G (A)	11,370		13,090		10,909		13,372
PSEG Power (A)	1,394		1,679		2,342		2,679
Total Long-Term Debt	$	15,695	$	17,800	$	16,180	$	19,143

(A)Given that these bonds do not trade actively, the fair value amounts of taxable debt securities (primarily Level 2 measurements) are generally determined by a valuation model that is based on a conventional discounted cash flow methodology. The fair value amounts above do not represent the price at which the outstanding debt may be called for redemption by each issuer under their respective debt agreements.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 15. Other Income (Deductions)

	PSE&G		PSEG Power		Other (A)		Consolidated
	Millions
Three Months Ended June 30, 2021
NDT Fund Interest and Dividends	$	—	$	14	$	—	$	14
Allowance for Funds Used During Construction	19		—		—		19
Solar Loan Interest	4		—		—		4
Purchases of Tax Losses under New Jersey Technology Tax Benefit Transfer Program	—		(3)		—		(3)
Other	1		(3)		1		(1)
Total Other Income (Deductions)	$	24	$	8	$	1	$	33
Six Months Ended June 30, 2021
NDT Fund Interest and Dividends	$	—	$	27	$	—	$	27
Allowance for Funds Used During Construction	42		—		—		42
Solar Loan Interest	7		—		—		7
Purchases of Tax Losses under New Jersey Technology Tax Benefit Transfer Program	—		(19)		—		(19)
Other	3		(4)		2		1
Total Other Income (Deductions)	$	52	$	4	$	2	$	58
Three Months Ended June 30, 2020
NDT Fund Interest and Dividends	$	—	$	14	$	—	$	14
Allowance for Funds Used During Construction	20		—		—		20
Solar Loan Interest	4		—		—		4
Purchases of Tax Losses under New Jersey Technology Tax Benefit Transfer Program	—		(1)		—		(1)
Other	2		(1)		—		1
Total Other Income (Deductions)	$	26	$	12	$	—	$	38
Six Months Ended June 30, 2020
NDT Fund Interest and Dividends	$	—	$	27	$	—	$	27
Allowance for Funds Used During Construction	41		—		—		41
Solar Loan Interest	8		—		—		8
Purchases of Tax Losses under New Jersey Technology Tax Benefit Transfer Program	—		(36)		—		(36)
Other	4		(2)		—		2
Total Other Income (Deductions)	$	53	$	(11)	$	—	$	42

(A)Other consists of activity at PSEG (as parent company), Energy Holdings, Services, PSEG LI and intercompany eliminations.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 16. Income Taxes

A reconciliation of reported income tax expense for PSEG with the amount computed by multiplying pre-tax income by the statutory federal income tax rate of 21% is as follows:

	Three Months Ended						Six Months Ended
PSEG	June 30,						June 30,
	2021			2020			2021			2020
	Millions
Pre-Tax Income (Loss)	$	(239)		$	560		$	526		$	1,052
Tax Computed at Statutory Rate @ 21%	$	(50)		$	118		$	110		$	221
Increase (Decrease) Attributable to Flow-Through of Certain Tax Adjustments:
State Income Taxes (net of federal income tax)	(24)			25			18			32
NDT Fund	9			24			18			(2)
Tax Credit Amortization/ITC Recapture	35			(4)			31			(8)
Tax Adjustment Credit	(42)			(45)			(121)			(88)
Other	10			(9)			(1)			(2)
Subtotal	(12)			(9)			(55)			(68)
Total Income Tax Expense (Benefit)	$	(62)		$	109		$	55		$	153
Effective Income Tax Rate	25.9		%	19.5		%	10.5		%	14.5		%

A reconciliation of reported income tax expense for PSE&G with the amount computed by multiplying pre-tax income by the statutory federal income tax rate of 21% is as follows:

	Three Months Ended						Six Months Ended
PSE&G	June 30,						June 30,
	2021			2020			2021			2020
	Millions
Pre-Tax Income	$	370		$	330		$	926		$	879
Tax Computed at Statutory Rate @ 21%	$	78		$	69		$	194		$	185
Increase (Decrease) Attributable to Flow-Through of Certain Tax Adjustments:
State Income Taxes (net of federal income tax)	25			17			63			54
Tax Adjustment Credit	(42)			(45)			(121)			(88)
Other	—			6			4			5
Subtotal	(17)			(22)			(54)			(29)
Total Income Tax Expense (Benefit)	$	61		$	47		$	140		$	156
Effective Income Tax Rate	16.5		%	14.2		%	15.1		%	17.7		%

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

A reconciliation of reported income tax expense for PSEG Power with the amount computed by multiplying pre-tax income by the statutory federal income tax rate of 21% is as follows:

	Three Months Ended						Six Months Ended
PSEG Power	June 30,						June 30,
	2021			2020			2021			2020
	Millions
Pre-Tax Income (Loss)	$	(610)		$	234		$	(397)		$	177
Tax Computed at Statutory Rate @ 21%	$	(128)		$	49		$	(83)		$	37
Increase (Decrease) Attributable to Flow-Through of Certain Tax Adjustments:
State Income Taxes (net of federal income tax)	(49)			10			(45)			(21)
NDT Fund	9			24			18			(2)
Tax Credit Amortization/ITC Recapture	38			(2)			36			(4)
Audit Settlement	—			(20)			(2)			(22)
Other	3			3			1			6
Subtotal	1			15			8			(43)
Total Income Tax Expense (Benefit)	$	(127)		$	64		$	(75)		$	(6)
Effective Income Tax Rate	20.8		%	27.4		%	18.9		%	(3.4)		%

In March 2021, the White House released an overview of the American Jobs Plan. In April 2021, the Treasury Department issued The Made in America Tax Plan and in June 2021, the General Explanations of the Administration’s Fiscal Year 2022 Revenue Proposals in the Fiscal Year 2022 Budget. Each include several tax raising provisions that have not yet been enacted. Further, a prolonged economic recovery may result in additional federal and state tax legislation that can have a material impact on PSEG’s, PSE&G’s and PSEG Power’s effective tax rate and cash tax position.

Amounts recorded under the Tax Cuts and Jobs Act of 2017, Coronavirus Aid, Relief, and Economic Security Act and Consolidated Appropriations Act, 2021 are subject to change based on several factors, including, among other things, whether the Internal Revenue Service or state taxing authorities issue additional guidance and/or further clarification. Any further guidance or clarification could impact PSEG’s, PSE&G’s and PSEG Power’s financial statements.

As of June 30, 2021, PSE&G had a $23 million New Jersey Corporate Business Tax net operating loss (NOL) that is expected to be fully realized in the future. There are no other material tax carryforwards in other jurisdictions.

New Jersey State Tax Reform

In September 2020, New Jersey enacted its State Fiscal Year 2021 Budget, which amended the temporary surtax originally enacted into law in 2018, from 1.5% to 2.5% for 2020 and 2021 and extended the 2.5% surtax to 2023. PSE&G continues to be exempt and this amendment will not have a material impact on PSEG’s and PSEG Power’s financial statements.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 17. Accumulated Other Comprehensive Income (Loss), Net of Tax

PSEG	Three Months Ended June 30, 2021
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of March 31, 2021	$	(8)	$	(542)	$	8	$	(542)
Other Comprehensive Income (Loss) before Reclassifications	—		—		16		16
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	—		4		—		4
Net Current Period Other Comprehensive Income (Loss)	—		4		16		20
Balance as of June 30, 2021	$	(8)	$	(538)	$	24	$	(522)
PSEG	Three Months Ended June 30, 2020
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of March 31, 2020	$	(18)	$	(496)	$	33	$	(481)
Other Comprehensive Income (Loss) before Reclassifications	—		—		30		30
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	3		3		(10)		(4)
Net Current Period Other Comprehensive Income (Loss)	3		3		20		26
Balance as of June 30, 2020	$	(15)	$	(493)	$	53	$	(455)
PSEG	Six Months Ended June 30, 2021
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of December 31, 2020	$	(9)	$	(545)	$	50	$	(504)
Other Comprehensive Income (Loss) before Reclassifications	—		—		(24)		(24)
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	1		7		(2)		6
Net Current Period Other Comprehensive Income (Loss)	1		7		(26)		(18)
Balance as of June 30, 2021	$	(8)	$	(538)	$	24	$	(522)
PSEG	Six Months Ended June 30, 2020
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of December 31, 2019	$	(15)	$	(499)	$	25	$	(489)
Other Comprehensive Income (Loss) before Reclassifications	(4)		—		44		40
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	4		6		(16)		(6)
Net Current Period Other Comprehensive Income (Loss)	—		6		28		34
Balance as of June 30, 2020	$	(15)	$	(493)	$	53	$	(455)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

PSEG Power	Three Months Ended June 30, 2021
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of March 31, 2021	$	—	$	(457)	$	8	$	(449)
Other Comprehensive Income (Loss) before Reclassifications	—		—		13		13
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	—		3		(1)		2
Net Current Period Other Comprehensive Income (Loss)	—		3		12		15
Balance as of June 30, 2021	$	—	$	(454)	$	20	$	(434)
PSEG Power	Three Months Ended June 30, 2020
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of March 31, 2020	$	—	$	(418)	$	26	$	(392)
Other Comprehensive Income (Loss) before Reclassifications	—		—		24		24
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	—		3		(9)		(6)
Net Current Period Other Comprehensive Income (Loss)	—		3		15		18
Balance as of June 30, 2020	$	—	$	(415)	$	41	$	(374)
PSEG Power	Six Months Ended June 30, 2021
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of December 31, 2020	$	—	$	(459)	$	40	$	(419)
Other Comprehensive Income (Loss) before Reclassifications	—		—		(18)		(18)
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	—		5		(2)		3
Net Current Period Other Comprehensive Income (Loss)	—		5		(20)		(15)
Balance as of June 30, 2021	$	—	$	(454)	$	20	$	(434)
PSEG Power	Six Months Ended June 30, 2020
Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges		Pension and OPEB Plans		Available-for-Sale Securities		Total
	Millions
Balance as of December 31, 2019	$	—	$	(420)	$	19	$	(401)
Other Comprehensive Income (Loss) before Reclassifications	—		—		35		35
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)	—		5		(13)		(8)
Net Current Period Other Comprehensive Income (Loss)	—		5		22		27
Balance as of June 30, 2020	$	—	$	(415)	$	41	$	(374)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

PSEG			Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement
			Three Months Ended									Six Months Ended
Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)		Location of Pre-Tax Amount In Statement of Operations	June 30, 2021									June 30, 2021
	Pre-Tax Amount				Tax (Expense) Benefit			After-Tax Amount			Pre-Tax Amount			Tax (Expense) Benefit			After-Tax Amount
			Millions
Cash Flow Hedges
Interest Rate Swaps		Interest Expense	$	(1)		$	1		$	—		$	(2)		$	1		$	(1)
Total Cash Flow Hedges			(1)			1			—			(2)			1			(1)
Pension and OPEB Plans
Amortization of Prior Service (Cost) Credit		Non-Operating Pension and OPEB Credits (Costs)	6			(2)			4			11			(3)			8
Amortization of Actuarial Loss		Non-Operating Pension and OPEB Credits (Costs)	(11)			3			(8)			(21)			6			(15)
Total Pension and OPEB Plans			(5)			1			(4)			(10)			3			(7)
Available-for-Sale Debt Securities
Realized Gains (Losses)		Net Gains (Losses) on Trust Investments	1			(1)			—			4			(2)			2
Total Available-for-Sale Debt Securities			1			(1)			—			4			(2)			2
Total			$	(5)		$	1		$	(4)		$	(8)		$	2		$	(6)		PSEG			Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement
---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---
			Three Months Ended									Six Months Ended
Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)		Location of Pre-Tax Amount In Statement of Operations	June 30, 2020									June 30, 2020
	Pre-Tax Amount				Tax (Expense) Benefit			After-Tax Amount			Pre-Tax Amount			Tax (Expense) Benefit			After-Tax Amount
			Millions
Cash Flow Hedges
Interest Rate Swaps		Interest Expense	$	(4)		$	1		$	(3)		$	(6)		$	2		$	(4)
Total Cash Flow Hedges			(4)			1			(3)			(6)			2			(4)
Pension and OPEB Plans
Amortization of Prior Service (Cost) Credit		Non-Operating Pension and OPEB Credits (Costs)	6			(1)			5			12			(3)			9
Amortization of Actuarial Loss		Non-Operating Pension and OPEB Credits (Costs)	(10)			2			(8)			(20)			5			(15)
Total Pension and OPEB Plans			(4)			1			(3)			(8)			2			(6)
Available-for-Sale Debt Securities
Realized Gains (Losses) and Impairments		Net Gains (Losses) on Trust Investments	17			(7)			10			26			(10)			16
Total Available-for-Sale Debt Securities			17			(7)			10			26			(10)			16
Total			$	9		$	(5)		$	4		$	12		$	(6)		$	6

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

PSEG Power			Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement
			Three Months Ended									Six Months Ended
Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)		Location of Pre-Tax Amount In Statement of Operations	June 30, 2021									June 30, 2021
	Pre-Tax Amount				Tax (Expense) Benefit			After-Tax Amount			Pre-Tax Amount			Tax (Expense) Benefit			After-Tax Amount
			Millions
Pension and OPEB Plans
Amortization of Prior Service (Cost) Credit		Non-Operating Pension and OPEB Credits (Costs)	$	5		$	(2)		$	3		$	10		$	(3)		$	7
Amortization of Actuarial Loss		Non-Operating Pension and OPEB Credits (Costs)	(9)			3			(6)			(17)			5			(12)
Total Pension and OPEB Plans			(4)			1			(3)			(7)			2			(5)
Available-for-Sale Debt Securities
Realized Gains (Losses)		Net Gains (Losses) on Trust Investments	1			—			1			3			(1)			2
Total Available-for-Sale Debt Securities			1			—			1			3			(1)			2
Total			$	(3)		$	1		$	(2)		$	(4)		$	1		$	(3)		PSEG Power			Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement
---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---	---
			Three Months Ended									Six Months Ended
Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss)		Location of Pre-Tax Amount In Statement of Operations	June 30, 2020									June 30, 2020
	Pre-Tax Amount				Tax (Expense) Benefit			After-Tax Amount			Pre-Tax Amount			Tax (Expense) Benefit			After-Tax Amount
			Millions
Pension and OPEB Plans
Amortization of Prior Service (Cost) Credit		Non-Operating Pension and OPEB Credits (Costs)	$	6		$	(2)		$	4		$	11		$	(3)		$	8
Amortization of Actuarial Loss		Non-Operating Pension and OPEB Credits (Costs)	(9)			2			(7)			(17)			4			(13)
Total Pension and OPEB Plans			(3)			—			(3)			(6)			1			(5)
Available-for-Sale Debt Securities
Realized Gains (Losses) and Impairments		Net Gains (Losses) on Trust Investments	14			(5)			9			21			(8)			13
Total Available-for-Sale Debt Securities			14			(5)			9			21			(8)			13
Total			$	11		$	(5)		$	6		$	15		$	(7)		$	8

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 18. Earnings Per Share (EPS) and Dividends

EPS

Basic EPS is calculated by dividing Net Income (Loss) by the weighted average number of shares of common stock outstanding. Diluted EPS is calculated by dividing Net Income (Loss) by the weighted average number of shares of common stock outstanding, plus dilutive potential shares related to PSEG’s stock based compensation. The following table shows the effect of these dilutive potential shares on the weighted average number of shares outstanding used in calculating diluted EPS:

	Three Months Ended June 30,								Six Months Ended June 30,
	2021				2020				2021				2020
	Basic		Diluted		Basic		Diluted		Basic		Diluted		Basic		Diluted
EPS Numerator (Millions):
Net Income (Loss)	$	(177)	$	(177)	$	451	$	451	$	471	$	471	$	899	$	899
EPS Denominator (Millions):
Weighted Average Common Shares Outstanding	504		504		504		504		504		504		504		504
Effect of Stock Based Compensation Awards	—		—		—		3		—		3		—		3
Total Shares	504		504		504		507		504		507		504		507
EPS
Net Income (Loss)	$	(0.35)	$	(0.35)	$	0.89	$	0.89	$	0.94	$	0.93	$	1.78	$	1.77

Approximately three million potentially dilutive shares were excluded from total shares used to calculate the diluted loss per share for the quarter ended June 30, 2021 as their impact was antidilutive.

Dividends

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Dividend Payments on Common Stock	2021		2020		2021		2020
Per Share	$	0.51	$	0.49	$	1.02	$	0.98
In Millions	$	258	$	247	$	516	$	495

On July 20, 2021, the PSEG Board of Directors approved a $0.51 per share common stock dividend for the third quarter of 2021.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 19. Financial Information by Business Segment

	PSE&G		PSEG Power		Other (A)		Eliminations (B)		Consolidated Total
	Millions
Three Months Ended June 30, 2021
Total Operating Revenues	$	1,514	$	380	$	155	$	(175)	$	1,874
Net Income (Loss) (C)	309		$	(483)	(3)		—		(177)
Gross Additions to Long-Lived Assets	633		$	36	1		—		670
Six Months Ended June 30, 2021
Operating Revenues	$	3,587	$	1,547	$	306	$	(677)	$	4,763
Net Income (Loss) (C)	786		(322)		7		—		471
Gross Additions to Long-Lived Assets	1,219		82		2		—		1,303
Three Months Ended June 30, 2020
Total Operating Revenues	$	1,456	$	683	$	148	$	(237)	$	2,050
Net Income (Loss)	283		170		(2)		—		451
Gross Additions to Long-Lived Assets	570		121		3		—		694
Six Months Ended June 30, 2020
Operating Revenues	$	3,339	$	1,903	$	304	$	(715)	$	4,831
Net Income (Loss)	723		183		(7)		—		899
Gross Additions to Long-Lived Assets	1,190		218		6		—		1,414
As of June 30, 2021
Total Assets	$	36,396	$	11,031	$	2,669	$	(804)	$	49,292
Investments in Equity Method Subsidiaries	$	—	$	67	$	91	$	—	$	158
As of December 31, 2020
Total Assets	$	35,581	$	12,704	$	2,692	$	(927)	$	50,050
Investments in Equity Method Subsidiaries	$	—	$	64	$	—	$	—	$	64

(A)Includes amounts applicable to Energy Holdings and PSEG LI, which are below the quantitative threshold for separate disclosure as reportable segments. Other also includes amounts applicable to PSEG (parent company) and Services.

(B)Intercompany eliminations primarily relate to intercompany transactions between PSE&G and PSEG Power. For a further discussion of the intercompany transactions between PSE&G and PSEG Power, see Note 20. Related-Party Transactions.

(C)Includes a $373 million after-tax impairment of the ISO NE asset grouping at PSEG Power in the three and six months ended June 30, 2021. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments for additional information. Also includes net after-tax losses of $(206) million and $(77) million for the three months ended June 30, 2021 and 2020, respectively, and $(240) million for the six months ended June 30, 2021 related to the impacts of non-trading commodity mark-to-market activity, which consist of the financial impact from positions with future delivery dates.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

Note 20. Related-Party Transactions

The following discussion relates to intercompany transactions, which are eliminated during the PSEG consolidation process in accordance with GAAP.

PSE&G

The financial statements for PSE&G include transactions with related parties presented as follows:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Related-Party Transactions	2021		2020		2021		2020
	Millions
Billings from Affiliates:
Net Billings from PSEG Power (A)	$	172	$	227	$	667	$	717
Administrative Billings from Services (B)	92		78		179		156
Total Billings from Affiliates	$	264	$	305	$	846	$	873			As of		As of
---	---	---	---	---
Related-Party Transactions	June 30, 2021		December 31, 2020
	Millions
Payable to PSEG Power (A)	$	163	$	273
Payable to Services (B)	82		95
Payable to PSEG (C)	55		111
Accounts Payable—Affiliated Companies	$	300	$	479
Noncurrent Payable to PSEG Power (A)	$	10	$	—
Working Capital Advances to Services (D)	$	33	$	33
Long-Term Accrued Taxes Payable	$	4	$	7

PSEG Power

The financial statements for PSEG Power include transactions with related parties presented as follows:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Related-Party Transactions	2021		2020		2021		2020
	Millions
Billings to Affiliates:
Net Billings to PSE&G (A)	$	172	$	227	$	667	$	717
Billings from Affiliates:
Administrative Billings from Services (B)	$	46	$	42	$	89	$	87

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Table of Contents

	As of		As of
Related-Party Transactions	June 30, 2021		December 31, 2020
	Millions
Receivable from PSE&G (A)	$	163	$	273
Receivable from PSEG (C)	—		44
Receivable from Other	2		—
Accounts Receivable—Affiliated Companies	$	165	$	317
Payable to Services (B)	$	21	$	13
Payable to PSEG (C)	178		—
Accounts Payable—Affiliated Companies	$	199	$	13
Short-Term Loan to (from) Affiliate (E)	$	(121)	$	161
Noncurrent Receivable from PSE&G (A)	$	10	$	—
Working Capital Advances to Services (D)	$	17	$	17
Long-Term Accrued Taxes Payable	$	64	$	57

(A)PSE&G has entered into a requirements contract with PSEG Power under which PSEG Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. PSEG Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process and sells ZECs to PSE&G under the ZEC program. The rates in the BGS and BGSS contracts and for the ZEC sales are prescribed by the BPU. BGS and BGSS sales are billed and settled on a monthly basis. ZEC sales are billed on a monthly basis and settled annually following completion of each energy year. In addition, PSEG Power and PSE&G provide certain technical services for each other generally at cost in compliance with FERC and BPU affiliate rules.

(B)Services provides and bills administrative services to PSE&G and PSEG Power at cost. In addition, PSE&G and PSEG Power have other payables to Services, including amounts related to certain common costs, which Services pays on behalf of each of the operating companies.

(C)PSEG files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PSEG and each of its affiliated companies. The general operation of these agreements is that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PSEG. If there are NOLs and/or tax credits, the subsidiary shall receive payment for the tax savings from PSEG to the extent that PSEG is able to utilize those benefits.

(D)PSE&G and PSEG Power have advanced working capital to Services. The amounts are included in Other Noncurrent Assets on PSE&G’s and PSEG Power’s Condensed Consolidated Balance Sheets.

(E)PSEG Power’s short-term loans with PSEG are for working capital and other short-term needs. Interest Income and Interest Expense relating to these short-term funding activities were immaterial.

Table of Contents

ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (MD&A)

This combined MD&A is separately filed by Public Service Enterprise Group Incorporated (PSEG), Public Service Electric and Gas Company (PSE&G) and PSEG Power LLC (PSEG Power). Information contained herein relating to any individual company is filed by such company on its own behalf. PSE&G and PSEG Power each make representations only as to itself and make no representations whatsoever as to any other company.

PSEG’s business consists of two reportable segments, our principal direct wholly owned subsidiaries, which are:

•PSE&G—which is a public utility engaged principally in the transmission of electricity and distribution of electricity and natural gas in certain areas of New Jersey. PSE&G is subject to regulation by the New Jersey Board of Public Utilities (BPU) and the Federal Energy Regulatory Commission (FERC). PSE&G also invests in regulated solar generation projects and energy efficiency and related programs in New Jersey, which are regulated by the BPU, and

•PSEG Power—which is a multi-regional energy supply company that integrates the operations of its merchant nuclear and fossil generating assets with its power marketing businesses and fuel supply functions through competitive energy sales in well-developed energy markets primarily in the Northeast and Mid-Atlantic United States through its principal direct wholly owned subsidiaries. PSEG Power’s subsidiaries are subject to regulation by FERC, the Nuclear Regulatory Commission (NRC), the Environmental Protection Agency (EPA) and the states in which they operate.

PSEG’s other direct wholly owned subsidiaries are: PSEG Long Island LLC (PSEG LI), which operates the Long Island Power Authority’s (LIPA) transmission and distribution (T&D) system under an Amended and Restated Operations Services Agreement (OSA); PSEG Energy Holdings L.L.C. (Energy Holdings), which earns it revenues from its portfolio of lease investments and holds our investment in offshore wind ventures; and PSEG Services Corporation (Services), which provides certain management, administrative and general services to PSEG and its subsidiaries at cost.

Our business discussion in Part I, Item 1. Business of our 2020 Annual Report on 10-K (Form 10-K) provides a review of the regions and markets where we operate and compete, as well as our strategy for conducting our businesses within these markets, focusing on operational excellence, financial strength and making disciplined investments. Our risk factor discussion in Part I, Item 1A. Risk Factors of Form 10-K provides information about factors that could have a material adverse impact on our businesses. The following supplements that discussion and the discussion included in the Executive Overview of 2020 and Future Outlook provided in Item 7 in our Form 10-K by describing significant events and business developments that have occurred during 2021 and changes to the key factors that we expect may drive our future performance. The following discussion refers to the Condensed Consolidated Financial Statements (Statements) and the Related Notes to Condensed Consolidated Financial Statements (Notes). This discussion should be read in conjunction with such Statements, Notes and the Form 10-K.

EXECUTIVE OVERVIEW OF 2021 AND FUTURE OUTLOOK

We are progressing on our strategy to become a primarily regulated electric and gas utility and a contracted carbon-free energy infrastructure company. We are focused on meeting customer expectations and being well aligned with public policy objectives by investing to modernize our infrastructure, improve reliability and deliver cleaner energy. Our business plan focuses on achieving growth while controlling costs and managing the risks associated with regulatory and policy changes, fluctuating commodity prices and changes in customer demand. In furtherance of these goals, over the past few years, our investments have altered our business mix to reflect a higher percentage of earnings contribution by PSE&G, which improves the sustainability and predictability of our earnings and cash flows and provides more financial flexibility. In June 2021, we completed the sale of PSEG Power’s solar portfolio and we are continuing to advance the potential sale of PSEG Power’s more than 6,750 megawatts (MW) of fossil generation located in New Jersey, Connecticut, New York and Maryland. See Item 1. Note 4. Early Plant Retirements/Asset Dispositions and Impairments for additional information.

PSE&G, PSEG Power and PSEG LI are providing essential services during the coronavirus (COVID-19) pandemic. We have implemented a comprehensive set of enhanced safety actions to help protect our employees, customers and communities, and we will continue to closely monitor developments and adjust as needed to ensure that we provide reliable service while protecting the safety and health of our workforce and the communities we serve. We continue to be guided by the recommendations of health authorities at the federal, state and local levels.

The COVID-19 pandemic and associated government actions and economic effects continue to impact our businesses. We have incurred additional expenses to protect our employees and customers, and PSE&G is experiencing significantly higher bad debts and lower cash collections, as discussed below. The potential future impact of the pandemic and the associated economic impacts, which could extend beyond the duration of the pandemic, will depend on a number of factors outside of our control.

Table of Contents

These include the duration and severity of the outbreak as well as third-party actions taken to contain its spread and mitigate its public health effects, and governmental or regulatory actions regarding customer collections, potential limitations on rate increases, recovery of incremental costs, and other matters. While we currently cannot estimate the potential impact to our results of operations, financial condition and cash flows, this MD&A includes a discussion of potential effects of a prolonged outbreak.

PSE&G

At PSE&G, our focus is on enhancing reliability and resiliency of our T&D system, meeting customer expectations and supporting public policy objectives by investing capital in T&D infrastructure and clean energy programs. For the five-year period ending December 31, 2025, PSE&G expects to invest between $13 billion to $15 billion, resulting in an expected compound annual growth in rate base of 6.5% to 8%. The low end of the range assumes an extension of our Gas System Modernization Program (GSMP) and Clean Energy Future (CEF)-Energy Efficiency (EE) program at their average annual investment levels, as these programs are expected to continue at least at those current rates beyond their currently approved timeframe of 2023. The upper end of the range is driven by certain unapproved investment programs, including a to-be-filed extension of the Energy Strong program, which otherwise concludes in 2023, as well as the remaining portion of our CEF proposal (portion of Electric Vehicle (EV) and Energy Storage (ES) programs) and a potentially higher amount of investment for GSMP and CEF-EE beyond current levels.

In January 2020, New Jersey released its Energy Master Plan (EMP) which, among other things, recognized the importance of the State’s EE targets and supported EVs, ES, and advanced metering infrastructure (AMI).

In September 2020, PSE&G reached a settlement with parties in the CEF-EE proceeding, which the BPU approved. The settlement commits $1 billion over a three-year period, with the majority of the investment occurring over a five-year period. Costs will be recovered through annual rate-making, with returns aligned with our most recent base rate case and a ten-year amortization period.

The approval also included a Conservation Incentive Program (CIP), a mechanism that will provide for recovery of lost electric and gas variable margin revenues relative to a baseline of the test year in our last base rate case from July 2017 to June 2018. The deferral period for this mechanism became effective in June 2021 for electric and will become effective in October 2021 for gas. PSE&G will suspend its gas Weather Normalization Charge (WNC) when the gas deferral period begins.

In January 2021, the BPU approved a settlement with PSE&G and other parties in the CEF-Energy Cloud (EC) proceeding. The capital cost of the program, which includes implementation of AMI, is estimated to be approximately $700 million, invested over the next four years.

Also in January 2021, the BPU approved a settlement with PSE&G and other parties in the CEF-EV proceeding for a majority of the components of the program. The approved investment under the program is for $166 million, primarily relating to preparatory work to deliver infrastructure to the charging point for three programs: residential smart charging; Level-2 mixed use charging; and direct current fast charging.

All of the capital costs and expenses of the CEF-EC and CEF-EV programs are expected to be recovered in PSE&G’s next base rate case, expected in the second half of 2024. From the start of the program until the commencement of new base rates, the return on and of the capital portion of each of these programs, as well as expenses incurred to implement the CEF-EV program and operating costs and stranded costs associated with the retirement of existing meters under the CEF-EC program, will be deferred and included for recovery as part of our next rate case expected to be concluded in 2024. The remaining component of our CEF-EV proposal, the vehicle innovation subprogram, as well as the overall CEF-ES program, are being held in abeyance pending future policy guidance from the BPU.

We also continue to invest in transmission infrastructure in order to (i) maintain and enhance system integrity and grid reliability, (ii) ensure system resilience in the face of continued extreme weather conditions and cyber and physical security threats, (iii) address an aging transmission infrastructure, (iv) leverage technology to improve the operation of the system, (v) reduce transmission constraints, (vi) meet changing customer usage patterns and the demand for 24/7 electricity, and (vii) satisfy state public policy goals, including aggressive decarbonization agendas. Our planned capital spending for transmission in 2021-2023 is $2.5 billion. As discussed further below, PSE&G has reached a settlement with the BPU, pending FERC approval, to reduce its base transmission ROE from 11.18% to 9.9%.

The ongoing coronavirus pandemic and associated impacts could have several negative consequences, including potential delays of our regulatory agencies’ review and approval of proposed programs or rate recovery.

The coronavirus has also impacted PSE&G’s sales, with a reduction in demand from its commercial and industrial (C&I) customers, largely offset by increases in residential sales volumes. As a result, there has been no substantive net margin impact and future changes are largely addressed through the CIP mechanism that is effective in 2021. The most substantive impact of the pandemic on our financial position has been adverse changes to residential and C&I payment patterns. The State of New Jersey issued an Executive Order in March 2020 that included a moratorium on non-safety related service disconnections for

Table of Contents

non-payment. On June 30, 2021, the moratorium imposed by the State of New Jersey ended but the State has established a “grace period” prohibiting disconnections for residential customers through December 31, 2021. Given the annual winter moratorium on residential shut-offs, collections and shut-offs will not be in full effect until mid-March 2022. During the moratorium, PSE&G has experienced a significant decrease in cash inflow and higher Accounts Receivable aging and an associated increase in bad debt expense, which we expect will continue through the grace period and winter moratorium and take the next several years to fully return to normal levels. PSE&G’s electric distribution bad debt expense is recoverable through its Societal Benefits Clause (SBC) mechanism. PSE&G has deferred its incremental gas distribution bad debt expense as a result of COVID-19 as a Regulatory Asset and will seek recovery of that cost, as well as other net incremental COVID-19 costs, in its next base rate case.

In July 2020, the BPU authorized regulated utilities in New Jersey, including PSE&G, to create a COVID-19-related Regulatory Asset by deferring on their books and records the prudently incurred incremental costs related to COVID-19 beginning on March 9, 2020 through September 30, 2021. Deferred costs are to be offset by any federal or state assistance that the utility may receive as a direct result of the COVID-19 pandemic. As of June 30, 2021, PSE&G has recorded a Regulatory Asset related to COVID-19 to defer incremental costs of $82 million, which PSE&G expects are probable of recovery under the BPU order. While we expect to continue to defer and ultimately recover these costs under the July BPU Order, no assurances can be given.

Given the ongoing prohibition on residential shut-offs, in July 2021, PSE&G, joined by other New Jersey gas distribution companies, made a filing with the BPU, noting that the current deferral period does not allow for proper consideration and inclusion of all incremental related expenses in a Regulatory Asset and requesting that the BPU extend the deferral of bad debt and related costs through the end of 2023.

While the impact on our results of operations, financial condition and cash flows for the six months ended June 30, 2021 has not been material, a prolonged coronavirus pandemic and the associated economic impacts, which could extend beyond the duration of the pandemic, could materially impact cash from operations, Accounts Receivable and bad debt expense.

PSEG Power

In July 2020, we announced that we are exploring strategic alternatives for PSEG Power’s non-nuclear generating fleet with the intention of accelerating the transformation of our business into a primarily regulated electric and gas utility, with a significantly contracted generation business. It is expected to reduce overall business risk and earnings volatility, improve PSEG’s business and financial profile and is consistent with PSEG’s climate strategy and sustainability efforts, which is to focus on clean energy investments, methane reduction, and carbon-free generation. PSEG intends to retain ownership of PSEG Power’s existing nuclear fleet.

In May 2021, PSEG Power Ventures LLC (Power Ventures), a direct wholly owned subsidiary of PSEG Power, entered into a purchase agreement with Quattro Solar, LLC, an affiliate of LS Power, relating to the sale by Power Ventures of 100% of its ownership interest in PSEG Solar Source LLC (Solar Source) including its related assets and liabilities. The transaction closed in June 2021. Any potential transaction involving PSEG Power’s more than 6,750 MW of fossil generation is expected to be completed either in the fourth quarter of 2021 or the first quarter of 2022.

There is no assurance that the strategic review will result in a sale or other disposition of all or any portion of the fossil generation assets on terms that are favorable to us, or at all. Any transaction would be subject to market conditions and customary closing conditions, including the receipt of all required regulatory approvals. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments.

At PSEG Power, we have sought to achieve operational excellence and manage costs in order to optimize cash flow generation from our fleet in light of low wholesale power and gas prices, environmental considerations and competitive market forces that reward efficiency and reliability. In the first six months of 2021, our natural gas and nuclear units generated 10.1 and 15.5 terawatt hours and operated at a capacity factor of 44.3% and 92.1%, respectively. Our commitments for load, such as basic generation service (BGS) in New Jersey and other bilateral supply contracts, are backed by this generation or may be combined with the use of physical commodity purchases and financial instruments from the market to optimize the economic efficiency of serving our obligations. PSEG Power’s hedging practices help to manage some of the volatility of the merchant power business. More than 75% of PSEG Power’s expected gross margin in 2021 relates to hedging of our energy margin, our expected revenues from the capacity market mechanisms, Zero Emission Certificate (ZEC) revenues and certain ancillary service payments such as reactive power.

As discussed further below under “Wholesale Power Market Design,” FERC issued an order establishing new rules for PJM’s capacity market, extending the PJM Minimum Offer Price Rule (MOPR) to include both new and existing resources that receive or are entitled to receive certain out-of-market payments, with certain exemptions. However, in July 2021, PJM submitted to FERC a proposal to replace the expanded MOPR with new provisions that accommodate state public policy programs that do not attempt to set the price of capacity. Under the PJM proposal, PSEG Power’s New Jersey nuclear plants

Table of Contents

that receive ZEC payments will not be subject to the new MOPR. PJM’s proposal requests that FERC approve the new provisions for the Reliability Pricing Model (RPM) auction that is scheduled to be held in December 2021. We cannot predict the outcome of the FERC proceeding.

PSEG LI

Following the effects of Tropical Storm Isaias, the New York Attorney General initiated an inquiry into PSEG LI’s preparation and response to the storm. In addition, the Department of Public Service (DPS) within the New York State Public Service Commission launched an investigation of the state’s electric service providers’, including PSEG LI’s, preparation and response to the storm. The DPS issued an interim storm investigation report finding that PSEG LI violated its Emergency Response Plan and DPS Regulations, and recommended that LIPA consider taking various actions, including terminating or renegotiating the OSA. LIPA also issued a report with recommendations for improvements to PSEG LI’s structure and processes and recommended that LIPA either renegotiate or terminate the OSA.

In December 2020, LIPA filed a complaint against PSEG LI in New York State court alleging multiple breaches of the OSA in connection with PSEG LI’s preparation for and response to Tropical Storm Isaias seeking specific performance and $70 million in damages. In June 2021, LIPA and PSEG LI executed a non-binding term sheet, which is expected to guide amendments to our OSA. The term sheet includes several changes to the OSA, including shifting a portion of our fixed revenues to incentive compensation and subjecting a portion of revenue to the potential imposition of penalties by the DPS due to certain performance failures by PSEG LI, and resolves all of LIPA’s claims related to Tropical Storm Isaias and the DPS investigation. Any amendments to the OSA will require the approval of the New York Attorney General and the New York Comptroller. The OSA contract term will continue through 2025, with a mutual option to extend. No assurances can be given regarding reaching final settlement agreement, obtaining New York approvals and the closing of the inquiry by the Attorney General.

In the event that a final settlement with LIPA is not reached, PSEG LI intends to vigorously defend itself with regard to the allegations in LIPA’s complaint alleging breaches of the OSA. A decision in this proceeding requiring specific performance or the payment of damages by PSEG LI or resulting in the termination of the OSA could have a material adverse effect on PSEG’s results of operations and financial condition.

Climate Strategy and Sustainability Efforts

For more than a century, our mission has been to provide safe access to an around-the-clock supply of reliable, affordable energy. Building on this mission, we are working toward a future where customers universally use less energy, the energy they use is cleaner, and its delivery is more reliable and more resilient. In June 2021, we accelerated and expanded our net zero vision by 20 years, establishing a net zero carbon emissions by 2030 goal that includes direct greenhouse gas (GHG) emissions (Scope 1) and indirect GHG emissions from operations (Scope 2) at both PSEG Power and PSE&G, assuming advances in technology, public policy and customer behavior. Scope 1 emissions include power generation, methane leaks, vehicle fleet emissions, sulfur hexafluoride and refrigerant leaks. Scope 2 emissions include both gas and electric purchased energy for our PSE&G facilities and line losses.

PSE&G has undertaken a number of initiatives that support the reduction of GHG emissions and the implementation of energy efficiency initiatives. The first phase of our GSMP replaced approximately 450 miles of cast-iron and unprotected steel gas infrastructure, and the second phase of this program is expected to replace an additional 875 miles of gas pipes through 2023. The GSMP is designed to significantly reduce gas leaks in our distribution system, which would reduce the release of methane, a potent GHG, into the air. Through GSMP II, from 2018 through 2023 we expect an approximate 22% reduction in methane, and assuming a continuation of GSMP, we expect an approximate 60% reduction in methane emissions from 2011 through 2030. In addition, PSE&G’s recently approved CEF-EE, CEF-EC and CEF-EV programs and the proposed CEF-ES program are intended to support New Jersey’s EMP through programs designed to help customers increase their energy efficiency, support the expansion of the electric vehicle infrastructure in the State, install energy storage capacity to supplement solar generation and enhance grid resiliency, install smart meters and supporting infrastructure to allow for the integration of other clean energy technologies and to more efficiently respond to weather and other outage events. We also continue to assess physical risks of climate change and adapt our capital investment program to improve the reliability and resiliency of our system in an environment of increasing frequency and severity of weather events, notably through our investments in Energy Strong.

Offshore Wind

In December 2020, PSEG entered into a definitive agreement with Ørsted North America to acquire a 25% equity interest in Ørsted’s Ocean Wind project. Ocean Wind was selected by New Jersey to be the first offshore wind farm as part of the State’s intention to add 7,500 MW of offshore wind generating capacity by 2035. The Ocean Wind project is expected to achieve full commercial operation in 2025. On March 31, 2021, the BPU approved PSEG’s investment in Ocean Wind and the acquisition was completed in April 2021. Additionally, PSEG and Ørsted each owns 50% of Garden State Offshore Energy LLC (GSOE) which holds rights to an offshore wind lease area just south of New Jersey. PSEG and Ørsted are exploring opportunities to

Table of Contents

develop the GSOE lease area. In April 2021, PJM announced the opening of the first public policy Order 1000 bid window that would utilize the state agreement approach for transmission projects to support the full 7,500 MW of offshore wind generation that New Jersey plans to procure. The state agreement approach requires customers in the requesting state - in this case New Jersey - to pay for the costs of these public policy transmission projects. Bids for this opportunity are due in the third quarter of 2021 and PSEG is evaluating opportunities to bid in this open window.

Operational Excellence

We emphasize operational performance while developing opportunities in both our regulated and competitive businesses. In the first six months of 2021, our utility continued its efforts to control costs while maintaining strong operational performance.

Financial Strength

Our financial strength is predicated on a solid balance sheet, positive operating cash flow and reasonable risk-adjusted returns on increased investment. Our financial position remained strong during the first six months of 2021 as we

•maintained sufficient liquidity,

•maintained solid investment grade credit ratings, and

•increased our indicative annual dividend for 2021 to $2.04 per share.

We expect to be able to fund our planned capital requirements, as described in Liquidity and Capital Resources without the issuance of new equity. Our planned capital requirements, which are driven by growth in our regulated utility, and the potential sale of our fossil generating fleet are expected to improve our business and financial profile.

Financial Results

The results for PSEG, PSE&G and PSEG Power for the three months and six months ended June 30, 2021 and 2020 are presented as follows:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Earnings (Losses)	2021		2020		2021		2020
	Millions
PSE&G	$	309	$	283	$	786	$	723
PSEG Power (A)	(483)		170		(322)		183
Other (B)	(3)		(2)		7		(7)
PSEG Net Income (Loss)	$	(177)	$	451	$	471	$	899
PSEG Net Income (Loss) Per Share (Diluted)	$	(0.35)	$	0.89	$	0.93	$	1.77

(A)Includes a $373 million after-tax impairment of the New England (NE) asset grouping. See Note 4. Early Plant Retirements/Asset Dispositions and Impairments for additional information.

(B)Other includes after-tax activities at the parent company, PSEG LI, and Energy Holdings as well as intercompany eliminations.

PSEG Power’s results above include the Nuclear Decommissioning Trust (NDT) Fund activity and the impacts of non-trading commodity mark-to-market (MTM) activity, which consist of the financial impact from positions with future delivery dates.

The variances in our Net Income attributable to changes related to the NDT Fund and MTM are shown in the following table:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2021		2020		2021		2020
	Millions, after tax
NDT Fund Income (Expense) (A) (B)	$	47	$	118	$	79	$	(17)
Non-Trading MTM Gains (Losses) (C)	$	(206)	$	(77)	$	(240)	$	—

(A)NDT Fund Income (Expense) includes gains and losses on NDT securities which are recorded in Net Gains (Losses) on Trust Investments. See Item 1. Note 9. Trust Investments for additional information. NDT Fund Income (Expense) also includes interest and dividend income and other costs related to the NDT Fund recorded in Other Income

Table of Contents

(Deductions), interest accretion expense on PSEG Power’s nuclear Asset Retirement Obligation (ARO) recorded in Operation and Maintenance (O&M) Expense and the depreciation related to the ARO asset recorded in Depreciation and Amortization (D&A) Expense.

(B)Net of tax (expense) benefit of $(30) million and $(74) million for the three months and $(53) million and $10 million for the six months ended June 30, 2021 and 2020, respectively.

(C)Net of tax (expense) benefit of $79 million and $30 million for the three months ended June 30, 2021 and 2020, respectively, and $92 million for the six months ended June 30, 2021.

Our $628 million and $428 million decreases in Net Income for the three months and six months ended June 30, 2021, respectively, were driven primarily by

•an impairment of the NE fossil asset grouping at PSEG Power (see Note 4. Early Plant Retirements/Asset Dispositions and Impairments for additional information), and

•higher MTM losses at PSEG Power,

•partially offset by higher earnings due to continued investments in T&D programs at PSE&G, and

•higher pension and OPEB credits.

The decrease in Net Income for the three month period was also due to lower net gains on NDT Fund equity securities whereas the decrease in Net Income for the six month period was partially offset by net gains on NDT Fund equity securities as compared to net losses in 2020 at PSEG Power.

Disciplined Investment

We utilize rigorous criteria and consider a number of external factors, focusing on the value for our stakeholders, as well as other impacts, when determining how and when to efficiently deploy capital. We principally explore opportunities for investment in areas that complement our existing business and provide reasonable risk-adjusted returns and continuously assess and optimize our business mix as appropriate. In the first six months of 2021, we

•made additional investments in T&D infrastructure projects on time and on budget,

•continued to execute our Energy Efficiency and other existing BPU-approved utility programs,

•closed on our acquisition of a 25% equity interest in the Ocean Wind project,

•continued to evaluate potential additional offshore wind opportunities, and

•completed the sale of PSEG Power’s Solar Source units and continue the process to potentially sell the fossil generation business.

Regulatory, Legislative and Other Developments

In our pursuit of operational excellence, financial strength and disciplined investment, we closely monitor and engage with stakeholders on significant regulatory and legislative developments. Transmission planning rules and wholesale power market design are of particular importance to our results and we continue to advocate for policies and rules that promote fair and efficient electricity markets. For additional information about regulatory, legislative and other developments that may affect us, see Part I, Item 1. Business—Regulatory Issues in our Form 10-K and Item 5. Other Information in our Quarterly Report on Form 10-Q for the period ending March 31, 2021 (first quarter 2021 10-Q) and this Quarterly Report on Form 10-Q.

Transmission Rate Proceedings and Return on Equity (ROE)

In March 2019, FERC issued a Notice of Inquiry seeking comments on improvements to FERC’s electric transmission incentives policy. Subsequently, in April 2021, FERC issued a supplemental notice of proposed rulemaking to eliminate the incentive for Regional Transmission Organization (RTO) membership for transmitting utilities that have already received the incentive for three or more years. PSE&G began receiving a 50 basis point adder for RTO membership in 2008. Elimination of the adder for RTO membership could reduce PSE&G’s annual Net Income and annual cash inflows by approximately $30 million.

In May 2020, FERC issued an order revising an earlier order that established a new ROE policy for reviewing existing transmission owners’ ROEs. The revised methodology uses the Discounted Cash Flow model, the Capital Asset Pricing model and the Risk Premium model to determine if an existing base ROE is unjust and unreasonable and, if so, what replacement ROE is appropriate. FERC’s order indicated that it would not be bound by this revised methodology when considering the just and reasonableness of a utility’s ROE in future proceedings. We continue to analyze the potential impact of these methodologies.

ROE complaints have been pending before FERC regarding MISO transmission owners, the ISO New England Inc.

Table of Contents

transmission owners and utilities in other jurisdictions. In addition, over the past few years, several companies have negotiated settlements that have resulted in reduced ROEs.

In July 2021, we submitted for FERC’s approval a settlement agreement effective August 1, 2021 that we reached with the BPU and the New Jersey Division of Rate Counsel (New Jersey Rate Counsel) about the level of PSE&G’s base transmission ROE and other formula rate matters. The settlement reduces PSE&G’s base ROE from 11.18% to 9.9%. As a result of this settlement, PSE&G’s annual Net Income would decrease by approximately $50 million to $60 million, with a total decrease in cash flows of approximately $100 million. The settlement provides that the settling parties will not seek changes to our transmission formula rate for three years. We cannot predict the outcome of the FERC proceeding.

Wholesale Power Market Design

In December 2019, FERC issued an order establishing new rules for PJM’s capacity market, extending the PJM MOPR to include both new and existing resources that receive or are entitled to receive certain out-of-market payments, with certain exemptions. However, in July 2021, PJM submitted to FERC a proposal to replace the expanded MOPR with new provisions that accommodate state public policy programs if they do not attempt to set the price of capacity. PJM states that nuclear plants that receive ZEC payments such as PSEG Power’s New Jersey units will not be subject to the new MOPR provisions. PJM requests that FERC approve its proposal for the new RPM auction scheduled for December 2021. We cannot predict the outcome of the FERC proceeding.

In July 2021, the BPU issued a report on its investigation related to whether New Jersey can achieve its long-term clean energy and environmental objectives under the current resource adequacy procurement paradigm. The report found that participating in the regional market is the most efficient way for New Jersey to achieve its clean energy goals and therefore consideration of leaving the regional market is paused while important market reforms are being considered at the regional and national level. However, the report recommends that New Jersey continue to explore a New Jersey-only or regional competitive auction design if potential reforms at the regional and national level are not sufficient to allow New Jersey to achieve its clean energy goals. We cannot predict whether the BPU will take any measures in the future that will have an impact on the capacity market or our generating stations.

In January 2020, New Jersey rejoined the Regional Greenhouse Gas Initiative (RGGI). As a result, generating plants operating in New Jersey, including those owned by PSEG Power, that emit CO2 emissions will be required to procure credits for each ton they emit. In response to RGGI, PJM initiated a process in 2019 to investigate the development of a carbon pricing mechanism that may mitigate the environmental and financial distortions that could occur when emissions “leak” from non-participating states to the RGGI states. If the process leads to a market solution, it could have a material impact on the value of PSEG Power’s generating fleet.

Environmental Regulation

We are subject to liability under environmental laws for the costs and penalties of remediating environmental contamination of property now or formerly owned by us and of property contaminated by hazardous substances that we generated. In particular, the historic operations of PSEG companies and the operations of numerous other companies along the Passaic and Hackensack Rivers are alleged by Federal and State agencies to have discharged substantial contamination into the Passaic River/Newark Bay Complex in violation of various statutes. We are also currently involved in a number of proceedings relating to sites where other hazardous substances may have been discharged and may be subject to additional proceedings in the future, and the costs and penalties of any such remediation efforts could be material.

For further information regarding the matters described above, as well as other matters that may impact our financial condition and results of operations, see Item 1. Note 11. Commitments and Contingent Liabilities.

Nuclear

In April 2019, PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs by the BPU. Pursuant to a process established by the BPU, ZECs are purchased from selected nuclear plants and recovered through a non-bypassable distribution charge in the amount of $0.004 per kilowatt-hour used (which is equivalent to approximately $10 per megawatt hour (MWh) generated in payments to selected nuclear plants (ZEC payment)). Each nuclear plant is expected to receive ZEC revenue for approximately three years, through May 2022.

In April 2021, PSEG Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs for the three-year eligibility period starting June 2022 at the same approximate $10 per MWh received during the current ZEC period through May 2022 referenced above. As a result, each nuclear plant is expected to receive ZEC revenue for an additional three years starting June 2022. The terms and conditions of this April 2021 ZEC award are the same as the current ZEC period as discussed above. While the ZEC program has preserved these units to date, PSEG will seek a long-term legislative or other solution for our New Jersey nuclear plants that sufficiently values them for their carbon-free, fuel diversity and resilience attributes. No assurances can be given regarding future ZEC awards or other long-term solutions.

Table of Contents

The award of ZECs attaches certain obligations, including an obligation to repay the ZECs in the event that a plant ceases operations during the period that it was awarded ZECs, subject to certain exceptions specified in the ZEC legislation. PSEG Power has and will continue to recognize revenue monthly as the nuclear plants generate electricity and satisfy their performance obligations. Further, the ZEC payment may be adjusted by the BPU at any time to offset environmental or fuel diversity payments that a selected nuclear plant may receive from another source. For instance, the New Jersey Rate Counsel, in written comments filed with the BPU, has advocated for the BPU to offset market benefits resulting from New Jersey’s rejoining the RGGI from the ZEC payment. PSEG intends to vigorously defend against these arguments. Due to its preliminary nature, PSEG cannot predict the outcome of this matter.

The BPU’s April 2019 decision awarding ZECs through May 2022 and April 2021 decision awarding ZECs through May 2025 have been appealed by the New Jersey Rate Counsel. In May 2021, Rate Counsel filed an appeal with the New Jersey Appellate Division of the BPU’s April 2021 decision. In July 2021, the New Jersey Supreme Court denied the New Jersey Rate Counsel’s petition for further appellate review of the BPU’s April 2019 decision. PSEG cannot predict the outcome of these matters.

In the event that (i) the ZEC program is overturned or is otherwise materially adversely modified through legal process; or (ii) any of the Salem 1, Salem 2 and Hope Creek plants is not sufficiently valued for its environmental, fuel diversity or resilience attributes in future periods and does not otherwise experience a material financial change that would remove the need for such attributes to be sufficiently valued, PSEG Power will take all necessary steps to cease to operate all of these plants. Alternatively, even with sufficient valuation of these attributes, if the financial condition of the plants is materially adversely impacted by changes in commodity prices, FERC’s changes to the capacity market construct (absent sufficient capacity revenues provided under a program approved by the BPU in accordance with a FERC-authorized capacity mechanism), or, in the case of the Salem nuclear plants, decisions by the EPA and state environmental regulators regarding the implementation of Section 316(b) of the Clean Water Act and related state regulations, or other factors, PSEG Power will take all necessary steps to cease to operate all of these plants. Ceasing operations of these plants would result in a material adverse impact on PSEG’s and PSEG Power’s results of operations.

Tax Legislation

In March 2021, the White House released an overview of the American Jobs Plan. In April 2021, the Treasury Department issued The Made in America Tax Plan and in June 2021, the General Explanations of the Administration’s Fiscal Year 2022 Revenue Proposals in the Fiscal Year 2022 Budget. Each includes several tax-raising provisions that have not yet been enacted. The Made in America Tax Plan includes an increase in the federal corporate tax rate and a minimum tax levied on book earnings. If these provisions are enacted, it would have an unfavorable impact on PSEG’s and PSEG Power’s financial statements and would increase PSE&G’s customers’ bills.

A prolonged coronavirus pandemic or further economic stimulus could result in future federal or state legislation that could have a material impact on our effective tax rate and cash tax position.

The Consolidated Appropriations Act, 2021 (CAA) was enacted in late December 2020. The CAA provides a 30% investment tax credit (ITC) for offshore wind projects that begin construction before December 31, 2025. In addition, on December 31, 2020, Notice 2021-05 was issued. For qualifying offshore wind projects, the notice extends the four year continuity safe harbor to ten calendar years commencing the calendar year after which construction of the project begins.

In July 2020, the Internal Revenue Service (IRS) issued final and proposed regulations addressing the limitation on deductible business interest expense contained in the Tax Cuts and Jobs Act. These regulations retroactively allow depreciation to be added back in computing the 30% adjusted taxable income (ATI) cap, increasing the amount of interest that can be deducted by unregulated businesses in years before 2022. For 2022 and after, the regulations continue to disallow the addback of depreciation in the computation of ATI, effectively lowering the cap on the amount of deductible business interest. The portion of PSEG’s and PSEG Power’s business interest expense that was disallowed in 2018 and 2019 will now be deductible in those respective years.

In March 2020, the federal Coronavirus Aid, Relief, and Economic Security Act (CARES Act) was enacted. The CARES Act allows a five-year carryback of any net operating loss (NOL) generated in a taxable year beginning after December 31, 2017 and before January 1, 2021.

Future Outlook

Our future success will depend on our ability to continue to maintain strong operational and financial performance to capitalize on or otherwise address regulatory and legislative developments that impact our business and to respond to the issues and challenges described below. In order to do this, we will continue to:

•obtain approval of and execute on our utility capital investment program to enhance the resiliency of our infrastructure, maintain the reliability of the service we provide to our customers, and align our sustainability and climate goals with New Jersey’s energy policy,

Table of Contents

•focus on controlling costs while maintaining safety, reliability and customer satisfaction and complying with applicable standards and requirements,

•deliver on our Human Capital Management strategy to attract, develop and retain a diverse, high-performing workforce,

•successfully manage our energy obligations and re-contract our open supply positions in response to changes in prices and demand, mindful of the cost and affordability impacts to our electric and gas distribution customers,

•advocate for federal and state programs to properly value New Jersey’s largest carbon-free generation resource and measures that promote fair and efficient electricity markets, including recognition of the cost of emissions,

•engage constructively with our multiple stakeholders, including regulators, government officials, customers, employees, investors, suppliers and the communities in which we do business,

•finalize our strategic alternatives review for PSEG Power’s fossil generating assets and successfully execute any transactions involving those assets as we shift our business mix to a primarily regulated utility and contracted generating company with a carbon-free nuclear and regional offshore wind fleet,

•seek a fair return for our T&D investments through our transmission formula rate, distribution infrastructure and clean energy investment programs and periodic distribution base rate case proceedings,

•successfully operate the LIPA T&D system and manage LIPA’s fuel supply and generation dispatch obligations, and

•manage the risks and opportunities in environmental, social and governance (ESG) matters, which is an integral part of our long-term strategy to be a clean energy leader for the benefit of all stakeholders.

In addition to the risks described elsewhere in this Form 10-Q and in our Form 10-K, for 2021 and beyond, the key issues and challenges we expect our business to confront include:

•regulatory and political uncertainty, both with regard to future energy policy, design of energy and capacity markets, transmission policy and environmental regulation, as well as with respect to the outcome of any legal, regulatory or other proceedings,

•the continuing impact of the ongoing coronavirus pandemic and the associated regulations and economic impacts, which could extend beyond the duration of the pandemic,

•future changes in federal and state tax laws, including The American Jobs Plan and Made in America Tax Plan, and

•the impact of changes in demand, natural gas and electricity prices, and expanded efforts to decarbonize several sectors of the economy.

We continually assess a broad range of strategic options to maximize long-term stockholder value and address the interests of our multiple stakeholders. In assessing our options, we consider a wide variety of factors, including the performance and prospects of our businesses; the views of employees, investors, regulators, customers and rating agencies; our existing indebtedness and restrictions it imposes; and tax considerations, among other things. Strategic options available to us include:

•investments in T&D facilities to enhance reliability, resiliency and modernize the system to meet the growing needs and increasingly higher expectations of customers, and clean energy investments such as CEF-EE, CEF-EV and CEF-ES,

•the disposition or restructuring of our merchant generation business or portions thereof or other existing businesses or the acquisition or development of new businesses,

•investments in regional offshore wind with long-term contracts that provide revenue predictability and a reasonable risk-adjusted return,

•continued operation of our nuclear generation facilities, to the extent there is sufficient certainty that their operation will render an acceptable risk-adjusted return, and

•acquisitions, dispositions and other transactions involving assets or businesses that could provide value to customers and shareholders.

There can be no assurance, however, that we will successfully develop and execute any of the strategic options noted above, or any additional options we may consider in the future. The execution of any such strategic plan may not have the expected benefits or may have unexpected adverse consequences.

Table of Contents

RESULTS OF OPERATIONS

PSEG

Our results of operations are primarily comprised of the results of operations of our principal operating subsidiaries, PSE&G and PSEG Power, excluding charges related to intercompany transactions, which are eliminated in consolidation. For additional information on intercompany transactions, see Item 1. Note 20. Related-Party Transactions.

	Three Months Ended				Increase/<br>(Decrease)				Six Months Ended				Increase/<br>(Decrease)
	June 30,						June 30,
	2021		2020		2021 vs. 2020				2021		2020		2021 vs. 2020
	Millions				Millions			%	Millions				Millions		%
Operating Revenues	$	1,874	$	2,050	$	(176)		(9)	$	4,763	$	4,831	$	(68)	(1)
Energy Costs	606		595		11			2	1,635		1,501		134		9
Operation and Maintenance	783		733		50			7	1,561		1,487		74		5
Depreciation and Amortization	322		315		7			2	663		639		24		4
(Gains) Losses on Asset Dispositions and Impairments	457		—		457			N/A	457		—		457		N/A
Income from Equity Method Investments	6		3		3			100	9		6		3		50
Net Gains (Losses) on Trust Investments	81		201		(120)			(60)	141		(20)		161		N/A
Other Income (Deductions)	33		38		(5)			(13)	58		42		16		38
Net Non-Operating Pension and OPEB Credits (Costs)	82		62		20			32	164		124		40		32
Interest Expense	147		151		(4)			(3)	293		304		(11)		(4)
Income Tax (Benefit) Expense	(62)		109		(171)			N/A	55		153		(98)		(64)

The following discussions for PSE&G and PSEG Power provide a detailed explanation of their respective variances.

PSE&G

	Three Months Ended				Increase/<br>(Decrease)				Six Months Ended				Increase/<br>(Decrease)
	June 30,						June 30,
	2021		2020		2021 vs. 2020				2021		2020		2021 vs. 2020
	Millions				Millions			%	Millions				Millions		%
Operating Revenues	$	1,514	$	1,456	$	58		4	$	3,587	$	3,339	$	248	7
Energy Costs	509		510		(1)			—	1,358		1,218		140		11
Operation and Maintenance	393		380		13			3	817		766		51		7
Depreciation and Amortization	231		217		14			6	472		439		33		8
Net Gains (Losses) on Trust Investments	—		1		(1)			N/A	1		1		—		—
Other Income (Deductions)	24		26		(2)			(8)	52		53		(1)		(2)
Net Non-Operating Pension and OPEB Credits (Costs)	66		52		14			27	132		103		29		28
Interest Expense	101		98		3			3	199		194		5		3
Income Tax Expense (Benefit)	61		47		14			30	140		156		(16)		(10)

Three Months Ended June 30, 2021 as Compared to 2020

Operating Revenues increased $58 million due to changes in delivery, commodity, clause and other operating revenues.

Table of Contents

Delivery Revenues increased $53 million due primarily to

•Transmission revenues were $30 million higher due to an increase in revenue requirements attributable to higher rate base investment.

•Electric distribution revenues increased $21 million due primarily to a $17 million increase attributable to higher sales volumes and a $4 million increase in Green Program Recovery Charge (GPRC) collections.

•Gas distribution revenues increased $4 million due primarily to a $15 million increase related to WNC revenue accruals, a $6 million increase due to a rate roll-in for the GSMP II and a $1 million increase in GPRC revenues, partially offset by an $18 million decrease due to lower sales volumes in 2021.

•Electric and Gas revenues decreased $2 million due to a net increase in the flowback to customers of excess deferred tax liabilities and tax repair-related accumulated deferred income tax benefits resulting from rate reductions, which is offset in Income Tax Expense.

Commodity Revenues were flat as a result of higher Electric revenues offset by lower Gas revenues. The changes in Commodity revenues for both electric and gas are entirely offset by the changes in Energy Costs. PSE&G earns no margin on the provision of BGS to retail customers and basic gas supply service (BGSS).

•Electric commodity revenues increased $10 million due primarily to a $22 million increase in sales volumes, partially offset by $12 million in lower BGS prices.

•Gas commodity revenues decreased $10 million due primarily to lower BGSS sales volumes of $17 million, partially offset by higher BGSS prices of $7 million.

Clause Revenues decreased $1 million due primarily to a $7 million net decrease in the Tax Adjustment Credit (TAC) and GPRC deferrals, partially offset by higher SBC revenues of $4 million and $2 million of higher Margin Adjustment Clause (MAC) collections. The changes in TAC and GPRC deferral amounts and SBC and MAC revenues are entirely offset by changes in the amortization of Regulatory Assets and Regulatory Liabilities and related costs in O&M, D&A, Interest and Income Tax Expenses. PSE&G does not earn margin on TAC and GPRC deferrals or SBC and MAC revenues.

Other Operating Revenues increased $6 million due to a $7 million increase primarily due to appliance service revenues, $5 million from Transition Renewable Energy Certificate (TREC) revenues and a $2 million increase in ZEC revenues. These increases were partially offset by an $8 million decrease in Solar Renewable Energy Certificate (SREC) revenues. The changes in TREC, ZEC and SREC components of revenues are entirely offset by changes in Energy Costs.

Operating Expenses

Energy Costs decreased $1 million. This is entirely offset by changes in Commodity Revenues and Other Operating Revenues.

Operation and Maintenance increased $13 million due primarily to a $13 million increase in transmission expenditures, an $8 million increase in appliance service costs and a $7 million increase in clause and renewable-related expenses, partially offset by a $10 million decrease in net COVID-19 costs due to the timing of the 2020 deferrals and a $5 million decrease in distribution operations maintenance.

Depreciation and Amortization increased $14 million due primarily to additional plant placed in service.

Net Non-Operating Pension and OPEB Credits (Costs) increased $14 million due primarily to an $11 million decrease in interest cost and a $7 million increase in the expected return on plan assets, partially offset by a $2 million increase in the amortization of the net actuarial loss and a $2 million increase in the amortization of net prior service cost.

Interest Expense increased $3 million due primarily to a $2 million increase from net debt issuances in 2021 and a $1 million increase from net debt issuances in 2020.

Income Tax Expense increased $14 million due primarily to higher pre-tax income.

Six Months Ended June 30, 2021 as Compared to 2020

Operating Revenues increased $248 million due to changes in delivery, commodity, clause and other operating revenues.

Delivery Revenues increased $81 million due primarily to

•Transmission revenues were $56 million higher due to an increase in revenue requirements attributable to higher rate base investment.

•Electric distribution revenues increased $34 million due primarily to higher sales volumes.

•Gas distribution revenues increased $18 million due primarily to a $26 million increase due to higher sales volumes, a

Table of Contents

$24 million increase due to a rate roll-in for GSMP II and a $4 million increase in GPRC revenues. These increases were partially offset by a $36 million decrease related to WNC revenue accruals.

•Electric and Gas revenues decreased $27 million due to a net increase in the flowback to customers of excess deferred tax liabilities and tax repair-related accumulated deferred income tax benefits resulting from rate reductions, which is offset in Income Tax Expense.

Commodity Revenues increased $145 million as a result of higher Gas revenues and higher Electric revenues. The changes in Commodity revenues for both gas and electric are entirely offset by the changes in Energy Costs. PSE&G earns no margin on the provision of BGSS and BGS to retail customers.

•Gas commodity revenues increased $92 million due primarily to higher BGSS prices of $51 million and higher BGSS sales volumes of $41 million.

•Electric commodity revenues increased $53 million due primarily to an $88 million increase in sales volumes, partially offset by $35 million in lower BGS prices.

Clause Revenues increased $17 million due primarily to higher SBC revenues of $19 million and a $3 million increase in MAC credits. These increases were partially offset by a $4 million net decrease in TAC and GPRC deferrals. The changes in SBC and MAC revenues and TAC and GPRC deferral amounts are entirely offset by changes in the amortization of Regulatory Assets and Regulatory Liabilities and related costs in O&M, D&A, Interest and Income Tax Expenses. PSE&G does not earn margin on SBC and MAC revenues or TAC and GPRC deferrals.

Other Operating Revenues increased $5 million due primarily to a $13 million increase in TREC revenues, a $10 million increase primarily from appliance service revenues and a $1 million increase in ZEC revenues. These increases were partially offset by a $19 million decrease in SREC revenues. The changes in TREC, ZEC and SREC components of revenues are entirely offset by changes to Energy Costs.

Operating Expenses

Energy Costs increased $140 million. This is entirely offset by changes in Commodity Revenues and Other Operating Revenues.

Operation and Maintenance increased $51 million due primarily to a $27 million increase in clause and renewable-related expenses, a $15 million increase in appliance service costs, a $17 million increase in transmission expenditures and a $3 million increase in grounds maintenance for snow removal. These increases were partially offset by a $12 million decrease in COVID-19 costs due to the timing of the 2020 deferrals.

Depreciation and Amortization increased $33 million due primarily to a $26 million increase related to additional plant in service and a $5 million increase in the amortization of Regulatory Assets.

Net Non-Operating Pension and OPEB Credits (Costs) increased $29 million due primarily to a $22 million decrease in interest cost and a $13 million increase in the expected return on plan assets, partially offset by a $3 million increase in the amortization of the net actuarial loss and a $3 million increase in the amortization of net prior service cost.

Interest Expense increased $5 million due primarily to a $3 million increase from net debt issuances in 2021 and a $3 million increase from net debt issuances in 2020. These increases were partially offset by a decrease of $1 million due to a reduction in short-term borrowings.

Income Tax Expense decreased $16 million due primarily to an increase in the 2021 flowback of PSE&G’s excess deferred income tax liabilities and CEF program investments, partially offset by higher pre-tax income.

Table of Contents

PSEG Power

	Three Months Ended				Increase/<br>(Decrease)				Six Months Ended				Increase/<br>(Decrease)
	June 30,						June 30,
	2021		2020		2021 vs. 2020				2021		2020		2021 vs. 2020
	Millions				Millions			%	Millions				Millions		%
Operating Revenues	$	380	$	683	$	(303)		(44)	$	1,547	$	1,903	$	(356)	(19)
Energy Costs	271		323		(52)			(16)	953		999		(46)		(5)
Operation and Maintenance	259		225		34			15	481		466		15		3
Depreciation and Amortization	83		91		(8)			(9)	175		185		(10)		(5)
(Gains) Losses on Asset Dispositions and Impairments	457		—		457			N/A	457		—		457		N/A
Income from Equity Method Investments	6		3		3			100	9		6		3		50
Net Gains (Losses) on Trust Investments	79		196		(117)			(60)	137		(24)		161		N/A
Other Income (Deductions)	8		12		(4)			(33)	4		(11)		15		N/A
Net Non-Operating Pension and OPEB Credits (Costs)	11		9		2			22	23		17		6		35
Interest Expense	24		30		(6)			(20)	51		64		(13)		(20)
Income Tax Expense (Benefit)	(127)		64		(191)			N/A	(75)		(6)		(69)		N/A

Three Months Ended June 30, 2021 as Compared to 2020

Operating Revenues decreased $303 million due primarily to changes in generation and gas supply revenues.

Generation Revenues decreased $290 million due primarily to

•a net decrease of $218 million due to more MTM losses in 2021 as compared to 2020. Of this amount, there was a $295 million decrease due to changes in forward prices this year as compared to last year, partially offset by a $77 million increase due to less losses on positions reclassified to realized upon settlement in 2021 as compared to 2020,

•a net decrease of $61 million in electricity sold primarily due to a $29 million impact from the transfer of responsibility for firm transmission services under the BGS contracts from the BGS suppliers to the Electric Distribution Companies (EDCs), coupled with lower volumes sold, and

•a net decrease of $8 million due to lower prices in the PJM region, partially offset by higher volumes sold in the NE region.

Gas Supply Revenues decreased $13 million due primarily to

•a net decrease of $10 million in sales under the BGSS contract primarily due to lower sales volumes, and

•a decrease of $10 million due to MTM losses in 2021 as compared to MTM gains in 2020, primarily due to changes in forward prices,

•partially offset by a net increase of $7 million related to sales to third parties, of which $10 million was due to higher average sales prices, partially offset by a decrease of $3 million due to lower volumes sold.

Operating Expenses

Energy Costs represent the cost of generation, which includes fuel costs for generation as well as purchased energy in the market, and gas purchases to meet PSEG Power’s obligation under its BGSS contract with PSE&G. Energy Costs decreased $52 million due to

Generation costs decreased $47 million due primarily to

•a net decrease of $48 million due to more MTM gains in 2021 as compared to 2020. Of this amount, there was a $63 million decrease due to changes in forward prices this year as compared to last year, partially offset by a $15 million decrease due to less gains on positions reclassified to realized upon settlement in 2021 as compared to 2020, and

•a net decrease of $39 million in transmission costs primarily due to a $29 million impact from the transfer of

Table of Contents

responsibility for firm transmission services under BGS contracts from BGS suppliers to the EDCs, coupled with a $10 million decrease from changes in BGS and other load,

•partially offset by a net increase of $21 million in fuel costs due to higher gas prices in the NE region coupled with the utilization of higher volumes of gas in the PJM and New York (NY) regions,

•a net increase of $9 million due to the reversal in the second quarter of 2020 of a lower of cost or market (LOCOM) adjustment on oil inventory that resulted from a recovery in oil prices, and

•a net increase of $9 million primarily due to higher costs for Renewable Energy Credit (RECs) related to load contracts in NE region.

Gas costs decreased $5 million due mainly to

•a net decrease of $11 million related to sales under the BGSS contract, primarily due to lower sendout volumes,

•partially offset by a net increase of $6 million related to sales to third parties, of which $9 million was due to an increase in the average cost of gas, partially offset by a decrease of $3 million due to lower volumes sold.

Operation and Maintenance increased $34 million due primarily to higher outage costs in 2021 at our Hope Creek nuclear plant.

Depreciation and Amortization decreased $8 million due primarily to the sale of Solar Source in June 2021 and to the retirement of the Bridgeport Harbor Station 3 (BH3) effective May 31, 2021.

(Gains) Losses on Asset Dispositions and Impairments of $457 million reflects a $519 million impairment of the ISO-NE fossil asset grouping, offset by a $62 million gain from the sale of Solar Source.

Net Gains (Losses) on Trust Investments decreased $117 million due primarily to a $162 million decrease in net unrealized gains on equity investments in the NDT Fund, partially offset by a $48 million increase in net realized gains on NDT Fund investments.

Other Income (Deductions) decreased $4 million primarily due to higher purchases of NOL tax benefits in 2021 under the New Jersey Technology Tax Benefit Transfer Program.

Interest Expense decreased $6 million due primarily to $950 million of debt maturities in 2021 and $406 million of debt maturities and $96 million in PSEG Power notes that were redeemed as part of the debt exchange with PSEG in 2020.

Income Tax Expense decreased $191 million due primarily to lower pre-tax income, partially offset by the recapture of ITCs related to the sale of Solar Source.

Six Months Ended June 30, 2021 as Compared to 2020

Operating Revenues decreased $356 million due primarily to changes in generation and gas supply revenues.

Generation Revenues decreased $418 million due primarily to

•a net decrease of $420 million due to MTM losses in 2021 as compared to MTM gains in 2020. Of this amount, there was a $404 million decrease due to changes in forward prices this year as compared to last year coupled with a $16 million decrease due to more losses on positions reclassified to realized upon settlement in 2021 as compared to 2020, and

•a net decrease of $84 million in electricity sold primarily due to a $51 million impact from the transfer of responsibility for firm transmission services under the BGS contracts from the BGS suppliers to the EDCs, coupled with lower volumes sold,

•partially offset by a net increase of $73 million due primarily to higher average realized prices in the PJM, NE and NY regions coupled with higher volumes of electricity sold in the NE region. This was partially offset by lower volumes of electricity sold in the PJM region, and

•a net increase of $17 million in capacity revenues due primarily to increases in auction prices in the PJM region, partially offset by decreases in capacity prices and higher load obligations in the NE region.

Gas Supply Revenues increased $62 million due primarily to

•a net increase of $53 million in sales under the BGSS contract primarily due to higher sales volumes, and

•a net increase of $19 million related to sales to third parties, of which $34 million was due to higher average sales prices, partially offset by $15 million due to lower volumes sold,

Table of Contents

•partially offset by a decrease of $10 million due to higher MTM losses in 2021 as compared to 2020, primarily due to changes in forward prices.

Operating Expenses

Energy Costs represent the cost of generation, which includes fuel costs for generation as well as purchased energy in the market, and gas purchases to meet PSEG Power’s obligation under its BGSS contract with PSE&G. Energy Costs decreased $46 million due to

Generation costs decreased $89 million due primarily to

•a net decrease of $97 million due to net MTM gains in 2021 compared to MTM losses in 2020. Of this amount, there was a $79 million decrease due to changes in forward prices this year as compared to last year coupled with an $18 million decrease due to more gains on positions reclassified to realized upon settlement in 2021 as compared to 2020,

•a net decrease of $68 million in transmission costs primarily due to a $51 million impact from the transfer of responsibility for firm transmission services under BGS contracts from BGS suppliers to the EDCs, coupled with a $17 million decrease from changes in BGS and other load, and

•a decrease of $11 million due to a LOCOM adjustment on oil inventory caused by a decrease in oil demand and pricing in 2020,

•partially offset by a net increase of $68 million in fuel costs reflecting higher gas prices in the PJM, NY, and NE regions coupled with the utilization of higher volumes of coal in the NE region, and

•a net increase of $13 million due to higher costs for RECs related to load contracts in the PJM and NE regions.

Gas costs increased $43 million due mainly to

•a net increase of $29 million in costs related to sales under the BGSS contract, of which $42 million was due to higher sendout volumes, partially offset by a decrease of $13 million due to the lower average cost of gas, and

•a net increase of $14 million related to sales to third parties, of which $27 million was due to an increase in the average cost of gas, partially offset by a decrease of $13 million due to lower volumes sold.

Operation and Maintenance increased $15 million due primarily to a refueling outage in 2021 at our 100%-owned Hope Creek nuclear plant as compared to an outage in 2020 at our 57%-owned Salem 2 nuclear plant, partially offset by lower outage costs in 2021 at our fossil plants.

Depreciation and Amortization decreased $10 million due primarily to the sale of Solar Source and the retirement of BH3 in 2021.

(Gains) Losses on Asset Dispositions and Impairments of $457 million reflects a $519 million impairment of the ISO-NE fossil asset grouping, offset by a $62 million gain from the sale of Solar Source.

Net Gains (Losses) on Trust Investments increased $161 million due primarily to a $108 million increase in net realized gains on NDT Fund investments and a $52 million increase due to $13 million of net unrealized gains in 2021 as compared to $39 million of net unrealized losses on NDT Fund equity securities.

Other Income (Deductions) increased $15 million due primarily to lower purchases of NOL tax benefits in 2021 under the New Jersey Technology Tax Benefit Transfer Program.

Non-Operating Pension and OPEB Credits (Costs) increased $6 million due to a $7 million decrease in interest cost and a $3 million increase in the expected return on plan assets, partially offset by $2 million in co-owner charges and a $2 million increase in the amortization of net actuarial loss and net prior service cost.

Interest Expense decreased $13 million due primarily to lower interest expense due to $950 million of debt maturities in 2021 and $406 million of debt maturities and $96 million in PSEG Power notes that were redeemed as part of the debt exchange with PSEG in 2020.

Income Tax Expense decreased $69 million due primarily to lower pre-tax income, partially offset by the recapture of ITCs related to the sale of Solar Source, an additional trust tax on the NDT qualified fund net gains, the tax benefit in 2020 from changes in uncertain tax positions as a result of the settlement of the 2011-2016 federal income tax audits and the purchase of less New Jersey NOL tax benefits in 2021 as compared to 2020.

Table of Contents

LIQUIDITY AND CAPITAL RESOURCES

The following discussion of our liquidity and capital resources is on a consolidated basis, noting the uses and contributions, where material, of our two direct major operating subsidiaries.

Operating Cash Flows

We continue to expect our operating cash flows combined with cash on hand and financing activities to be sufficient to fund planned capital expenditures and shareholder dividends.

For the six months ended June 30, 2021, our operating cash flow decreased $615 million as compared to the same period in 2020. The net decrease was primarily due to the net changes from our subsidiaries, as discussed below, offset by tax refunds in 2021 as compared to tax payments in 2020 at Energy Holdings.

Current economic conditions have adversely impacted residential and C&I customer payment patterns. During the moratorium, as previously discussed, PSE&G has experienced a significant decrease in cash inflow and higher Accounts Receivable aging and an associated increase in bad debt expense, which we expect will extend beyond the duration of the coronavirus pandemic. While the impact on our results of operations, financial condition and cash flows for the six months ended June 30, 2021 was not material, a prolonged coronavirus pandemic and the associated economic impacts, which could extend beyond the duration of the pandemic, could materially impact cash from operations, Accounts Receivable and bad debt expense.

PSE&G

PSE&G’s operating cash flow decreased $319 million from $999 million to $680 million for the six months ended June 30, 2021, as compared to the same period in 2020, due primarily to increases in electric energy and vendor payables, higher tax payments in 2021 and a lower reduction in accounts receivable and unbilled revenues in 2021, partially offset by a net decrease in regulatory deferrals and higher earnings.

PSEG Power

PSEG Power’s operating cash flow decreased $272 million from $626 million to $354 million for the six months ended June 30, 2021, as compared to the same period in 2020, due to lower earnings and a $321 million reduction related to cash collateral posting requirements, partially offset by a decrease of $53 million in payments to counterparties.

Short-Term Liquidity

PSEG meets its short-term liquidity requirements, as well as those of PSEG Power, primarily through the issuance of commercial paper and, from time to time, short-term loans. PSE&G maintains its own separate commercial paper program to meet its short-term liquidity requirements. Each commercial paper program is fully back-stopped by its own separate credit facilities.

We continually monitor our liquidity and seek to add capacity as needed to meet our liquidity requirements. Each of our credit facilities is restricted as to availability and use to the specific companies as listed below; however, if necessary, the PSEG facilities can also be used to support our subsidiaries’ liquidity needs.

In March 2020, PSEG entered into a $300 million, 364-day term loan agreement which was prepaid in January 2021. In May and March 2021, PSEG entered into two 364-day variable rate term loan agreements for $750 million and $500 million, respectively. These term loans are not included in the credit facility amounts presented in the following table.

Our total credit facilities and available liquidity as of June 30, 2021 were as follows:

Company/Facility		As of June 30, 2021
	Total<br>Facility			Usage			Available<br>Liquidity
		Millions
PSEG		$	1,500		$	202		$	1,298
PSE&G		600			18			582
PSEG Power		2,100			125			1,975
Total		$	4,200		$	345		$	3,855

As of June 30, 2021, our credit facility capacity was in excess of our projected maximum liquidity requirements over our 12 month planning horizon, including access to external financing to meet redemptions. Our maximum liquidity requirements are based on stress scenarios that incorporate changes in commodity prices and the potential impact of PSEG Power losing its investment grade credit rating from S&P or Moody’s, which would represent a three level downgrade from its current Moody’s rating and a two level downgrade from its current S&P rating. In the event of a deterioration of PSEG Power’s credit rating,

Table of Contents

certain of PSEG Power’s agreements allow the counterparty to demand further performance assurance. The potential additional collateral that we would be required to post under these agreements if PSEG Power were to lose its investment grade credit rating was approximately $862 million and $840 million as of June 30, 2021 and December 31, 2020, respectively.

For additional information, see Item 1. Note 12. Debt and Credit Facilities.

Long-Term Debt Financing

•In May 2021, PSEG Power redeemed at par $700 million of 3.00% Senior Notes due to mature in June 2021,

•In June 2021, PSE&G retired $134 million of 9.25% Mortgage Bonds, Series CC at maturity, and

•In June 2021, PSEG Power redeemed at par $250 million of 4.15% Senior Notes due to mature in September 2021.

During the next twelve months,

•PSEG Power redeemed its $44 million of Pennsylvania Economic Development Financing Authority Variable Rate Bonds in August 2021, and

•PSEG has $300 million of 2.00% Senior Notes maturing in November 2021.

PSEG, PSEG Power, Energy Holdings, PSEG LI and Services participate in a corporate money pool, an aggregation of daily cash balances designed to efficiently manage their respective short-term liquidity needs, which are accounted for as intercompany loans. Servco does not participate in the corporate money pool. Servco’s short-term liquidity needs are met through an account funded and owned by LIPA.

For additional information see Item 1. Note 12. Debt and Credit Facilities.

Guarantor Financial Information

PSEG Power’s Senior Notes are fully and unconditionally guaranteed on a joint and several basis by its subsidiaries, PSEG Fossil LLC, PSEG Nuclear LLC and PSEG Energy Resources & Trade LLC. Each guarantor subsidiary is a wholly owned consolidated subsidiary of PSEG Power.

Summarized financial information is being presented, on a combined basis, only for PSEG Power (parent company) and the guarantors of PSEG Power’s Senior Notes, excluding investments in, and earnings (losses) from, subsidiaries that are not guarantors. All transactions between PSEG Power (parent company) and the guarantor subsidiaries are eliminated in the combined summarized financial information. The required disclosures for the year-to-date interim period and the most recent fiscal year are provided in the following tables.

Table of Contents

	Six Months Ended		Year Ended
	June 30, 2021		December 31, 2020
	Millions
Operating Revenues (A)	$	1,512	$	3,564
Operating Income (Loss)	$	(587)	$	598
Net Income (Loss)	$	(331)	$	597

(A)Operating Revenues include sales to affiliates of $670 million and $1,218 million, respectively for the six months ended June 30, 2021 and year ended December 31, 2020, respectively.

	As of		As of
	June 30, 2021		December 31, 2020
	Millions
Current Receivables from Subsidiaries and Affiliates	$	1,418	$	2,350
Total Current Assets	$	2,388	$	3,365
Noncurrent Receivables from Affiliates	$	27	$	17
Total Noncurrent Assets	$	7,260	$	7,228
Current Payables to Subsidiaries and Affiliates	$	582	$	258
Total Current Liabilities	$	1,155	$	1,734
Noncurrent Payables to Affiliates	$	64	$	57
Total Noncurrent Liabilities	$	3,846	$	4,027

Pension and NDT Fund Obligations

IRS minimum funding requirements for pension plans are determined based on the fund’s assets and liabilities at the end of a calendar year for the subsequent calendar year. In the event of a prolonged economic downturn, our contributions to the pension plans may increase in future periods to meet IRS minimum funding requirements. PSEG had accumulated funding credits totaling approximately $600 million through 2020, which represent historical contributions in excess of IRS minimum funding requirements, and these credits can be applied to offset any future cash contribution obligations.

In addition, the NRC requires a biennial filing of the NDT fund balances against the decommissioning liability estimate. Any funding shortfalls are required to be cured prior to the next NRC reporting period. To the extent of a prolonged economic downturn, our funding requirements may increase in future periods to meet NRC minimum funding requirements.

Common Stock Dividends

On July 20, 2021, our Board of Directors declared a $0.51 dividend per share of common stock for the third quarter of 2021. This reflects an indicative annual dividend rate of $2.04 per share. We expect to continue to pay cash dividends on our common stock; however, the declaration and payment of future dividends to holders of our common stock will be at the discretion of the Board of Directors and will depend upon many factors, including our financial condition, earnings, capital requirements of our businesses, alternate investment opportunities, legal requirements, regulatory constraints, industry practice and other factors that the Board of Directors deems relevant. For additional information related to cash dividends on our common stock, see Item 1. Note 18. Earnings Per Share (EPS) and Dividends.

Credit Ratings

If the rating agencies lower or withdraw our credit ratings, such revisions may adversely affect the market price of our securities and serve to materially increase our cost of capital and limit access to capital. Credit Ratings shown are for securities that we typically issue. Outlooks are shown for Issuer Credit Ratings and can be Stable, Negative, or Positive. In May 2021, Moody’s changed PSE&G’s outlook to Negative from Stable. There is no assurance that the ratings will continue for any given period of time or that they will not be revised by the rating agencies, if in their respective judgments, circumstances warrant. Each rating given by an agency should be evaluated independently of the other agencies’ ratings. The ratings should not be construed as an indication to buy, hold or sell any security.

Table of Contents

	Moody’s (A)	S&P (B)
PSEG
Outlook	Stable	Stable
Senior Notes	Baa1	BBB
Commercial Paper	P2	A2
PSE&G
Outlook	Negative	Stable
Mortgage Bonds	Aa3	A
Commercial Paper	P1	A2
PSEG Power
Outlook	Stable	Stable
Senior Notes	Baa1	BBB

(A)Moody’s ratings range from Aaa (highest) to C (lowest) for long-term securities and P1 (highest) to NP (lowest) for short-term securities.

(B)S&P ratings range from AAA (highest) to D (lowest) for long-term securities and A1 (highest) to D (lowest) for short-term securities.

CAPITAL REQUIREMENTS

We expect that all of our capital requirements over the next three years will come from a combination of internally generated funds and external debt financing. There were no material changes to our projected capital expenditures as compared to amounts disclosed in our 2020 Form 10-K.

PSE&G

During the six months ended June 30, 2021, PSE&G made capital expenditures of $1,219 million, primarily for T&D system reliability. This does not include expenditures for cost of removal, net of salvage, of $60 million, which are included in operating cash flows.

PSEG Power

During the six months ended June 30, 2021, PSEG Power made capital expenditures of $61 million, excluding $21 million for nuclear fuel, primarily related to various nuclear and fossil projects.

ACCOUNTING MATTERS

For information related to recent accounting matters, see Item 1. Note 2. Recent Accounting Standards.

ITEM 3.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The risk inherent in our market-risk sensitive instruments and positions is the potential loss arising from adverse changes in commodity prices, equity security prices and interest rates as discussed in the Notes to Condensed Consolidated Financial Statements. It is our policy to use derivatives to manage risk consistent with business plans and prudent practices. We have a Risk Management Committee comprised of executive officers who utilize a risk oversight function to ensure compliance with our corporate policies and risk management practices.

Additionally, we are exposed to counterparty credit losses in the event of non-performance or non-payment. We have a credit management process, which is used to assess, monitor and mitigate counterparty exposure. In the event of non-performance or non-payment by a major counterparty, there may be a material adverse impact on our financial condition, results of operations or net cash flows.

Commodity Contracts

The availability and price of energy-related commodities are subject to fluctuations from factors such as weather, environmental policies, changes in supply and demand, state and federal regulatory policies, market rules and other events. To reduce price risk caused by market fluctuations, we enter into supply contracts and derivative contracts, including forwards, futures, swaps

Table of Contents

and options with approved counterparties. These contracts, in conjunction with physical sales and other services, help reduce risk and optimize the value of owned electric generation capacity.

Value-at-Risk (VaR) Models

VaR represents the potential losses, under normal market conditions, for instruments or portfolios due to changes in market factors, for a specified time period and confidence level. We estimate VaR across our commodity businesses.

MTM VaR consists of MTM derivatives that are economic hedges. The MTM VaR calculation does not include market risks associated with activities that are subject to accrual accounting, primarily our generating facilities and some load-serving activities.

The VaR models used are variance/covariance models adjusted for the change of positions with 95% and 99.5% confidence levels and a one-day holding period for the MTM activities. The models assume no new positions throughout the holding periods; however, we actively manage our portfolio.

From April through June 2021, MTM VaR varied between a low of $7 million and a high of $33 million at the 95% confidence level. The range of VaR was wider for the three months ended June 30, 2021 as compared with the year ended December 31, 2020.

	MTM VaR
	Three Months Ended June 30, 2021		Year Ended December 31, 2020
	Millions
95% Confidence Level, Loss could exceed VaR one day in 20 days
Period End	$	31	$	16
Average for the Period	$	15	$	10
High	$	33	$	18
Low	$	7	$	5
99.5% Confidence Level, Loss could exceed VaR one day in 200 days
Period End	$	48	$	24
Average for the Period	$	24	$	16
High	$	52	$	29
Low	$	12	$	8

See Item 1. Note 13. Financial Risk Management Activities for a discussion of credit risk.

ITEM 4.CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

PSEG, PSE&G and PSEG Power

We have established and maintain disclosure controls and procedures as defined under Rule 13a-15(e) and 15d-15(e) promulgated under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) that are designed to provide reasonable assurance that information required to be disclosed in the reports that are filed or submitted under the Exchange Act is recorded, processed, summarized and reported and is accumulated and communicated to the Chief Executive Officer (CEO) and Chief Financial Officer (CFO) of each respective company, as appropriate, by others within the entities to allow timely decisions regarding required disclosure. We have established a disclosure committee which includes several key management employees and which reports directly to the CFO and CEO of each of PSEG, PSE&G and PSEG Power. The committee monitors and evaluates the effectiveness of these disclosure controls and procedures. The CFO and CEO of each of PSEG, PSE&G and PSEG Power have evaluated the effectiveness of the disclosure controls and procedures and, based on this evaluation, have concluded that disclosure controls and procedures at each respective company were effective at a reasonable assurance level as of the end of the period covered by the report.

Internal Controls

PSEG, PSE&G and PSEG Power

There have been no changes in internal control over financial reporting that occurred during the second quarter of 2021 that have materially affected, or are reasonably likely to materially affect, each registrant’s internal control over financial reporting.

Table of Contents

PART II. OTHER INFORMATION

ITEM 1.LEGAL PROCEEDINGS

We are party to various lawsuits and environmental and regulatory matters, including in the ordinary course of business. For information regarding material legal proceedings, including updates to information reported in Item 3 of Part I of the Form 10-K, see Part I, Item 1. Note 11. Commitments and Contingent Liabilities and Item 5. Other Information in the first quarter 2021 10-Q and in this Quarterly Report on Form 10-Q.

ITEM 1A.RISK FACTORS

The discussion of our business and operations in this Quarterly Report on Form 10-Q should be read together with the risk factors contained in Part I, Item 1A of our Form 10-K, which describes various risks and uncertainties that could have a material adverse impact on our business, prospects, financial position, results of operations or cash flows and could cause results to differ materially from those expressed elsewhere in this report. We expect that the risks and uncertainties described in this Form 10-Q and our Form 10-K will be further adversely impacted by the ongoing coronavirus pandemic and any related, sustained economic downturn, which could extend beyond the duration of the pandemic.

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

In December 2020, we entered into a share repurchase plan that complies with Rule 10b5-1 of the Exchange Act, as amended, solely with respect to the repurchase of shares to satisfy obligations under equity compensation awards that are expected to be issued in 2021 and the repurchase of shares to satisfy purchases by employees under the Employee Stock Purchase Plan during 2021. There are no remaining shares available for repurchase under the plan.

ITEM 5. OTHER INFORMATION

Certain information reported in the Form 10-K is updated below. Additionally, certain information is provided for new matters that have arisen subsequent to the filing of the Form 10-K and first quarter 2021 10-Q. References are to the related pages on the Form 10-K and the first quarter 2021 Form 10-Q.

Federal Regulation

Energy Clearing Prices

December 31, 2020 Form 10-K page 13 and March 31, 2021 Form 10-Q page 82. In April 2019, FERC issued an order directing PJM and NYISO to change their rules governing pricing for fast-start resources. In its Order, FERC found that current fast-start pricing practices are unjust and unreasonable because they do not allow prices to reflect the marginal cost of serving load. FERC required PJM and NYISO to make various changes to their respective tariffs to allow the start-up costs of fast-start resources to be reflected in prices, among other things. In August 2019, PJM stated that new tariff provisions would apply fast-start pricing to all eligible fast-start resources. However, in January 2020, FERC decided to hold the proceeding in abeyance in order to allow PJM and its stakeholders to address FERC’s concern that PJM’s pricing and dispatch are misaligned. In December 2020, FERC issued an order accepting aspects of PJM’s proposed reforms, but also directed PJM to submit an additional filing, including an implementation date. In February 2021, PJM submitted the additional filing. In May 2021, FERC accepted PJM’s compliance filing. Separately, FERC accepted an effective date of September 1, 2021 for implementation of the fast-start pricing rules.

Capacity Market Issues

December 31, 2020 Form 10-K page 13. In July 2021, PJM submitted to FERC a proposal to replace the expanded MOPR with new provisions that accommodate state public policy programs that do not attempt to set the price of capacity. Under the PJM proposal, PSEG Power’s New Jersey nuclear plants that receive ZEC payments will not be subject to the new MOPR. PJM’s proposal requests that FERC approve the new provisions for the RPM auction that is scheduled to be held in December 2021. We cannot predict the outcome of the FERC proceeding.

Transmission Rate Proceedings and Return on Equity

December 31, 2020 Form 10-K page 14. In July 2021, PSE&G submitted for FERC’s approval a settlement agreement effective August 1, 2021 that it reached with the BPU and the New Jersey Rate Counsel about the level of PSE&G’s base transmission ROE and other formula rate matters. The settlement reduces PSE&G’s base ROE from 11.18% to 9.9%. As a

Table of Contents

result of this settlement, PSE&G’s annual Net Income would decrease by approximately $50 million to $60 million, with a total decrease in cash flows of approximately $100 million. The settlement provides that the settling parties will not seek changes to PSE&G’s transmission formula rate for three years. PSEG cannot predict the outcome of the FERC proceeding.

Reliability Standards

December 31, 2021 Form 10-K page 15. The North American Electric Reliability Corporation is currently examining revised criteria for low-impact cyber systems, which could result in expanding the Critical Infrastructure Protection standards to a larger set of applicable cyber assets. This examination is expected to be completed in late 2021 or early 2022.

State Regulation

New Jersey Solar Initiatives

December 31, 2020 Form 10-K page 16. In April 2021, the BPU released a proposal for a permanent solar financial incentive program, designated the Successor Program, drawing heavily from the current TREC fixed incentive program. Under this proposal, a Successor Program REC will be awarded for each MWh produced by an eligible solar project. During the second quarter of 2021, the BPU conducted a series of stakeholder workshops and a public meeting on the proposal. In July 2021, the BPU issued an order formally establishing the Successor Solar Incentive (SuSI) Program to serve as the permanent program for providing solar incentives to qualified solar electric generation facilities. The program provides for administratively-set incentive payments applicable to net-metered projects of 5 MW or less and an annual competitive solicitation applicable to grid-supply projects and net-metered C&I projects in excess of 5 MW.

Environmental Matters

CO2 Regulation under the Clean Air Act

December 31, 2020 Form 10-K page 19. In June 2019, the EPA issued its final Affordable Clean Energy (ACE) rule as a replacement for the repealed Clean Power Plan, a GHG emission regulation for existing power plants. The ACE rule narrowly defines the “best system of emissions reductions” (BSER) as heat improvements to be applied only to an individual unit, excluding other potential mechanisms to address climate change. In September 2019, a coalition of power companies, including PSEG, filed a Petition for Review of the ACE rule with the D.C. Circuit challenging the EPA’s narrow interpretation of BSER. In January 2021, the D.C. Circuit vacated the ACE rule and remanded the rulemaking to the EPA for further consideration. In April 2021, a 19-state coalition, led by West Virginia, filed a petition with the U.S. Supreme Court to review the D.C. Circuit’s decision to vacate the ACE Rule. We cannot predict the outcome of this matter or estimate its impact on our business or results of operations.

New Jersey Protecting Against Climate Threats (NJ PACT)

December 31, 2020 Form 10-K page 19. In response to a New Jersey Executive Order, the New Jersey Department of Environmental Protection (NJDEP) has undertaken a regulatory reform effort that is designed to modernize environmental laws, referred to as New Jersey Protecting Against Climate Threats (NJ PACT). When fully implemented, NJ PACT is expected to result in changes to existing environmental regulation, modernizing air quality and environmental land use regulations that will enable governments, businesses and residents to effectively respond to current climate threats and reduce future climate damages. In June 2021, the NJDEP took the first step by publishing the Proposed Greenhouse Gas Monitoring and Reporting Rule. The NJDEP proposes to require gas utilities to submit an annual report on replacement of mains and service lines in the State and to quantify maintenance-venting events, referred to as blowdown events. In addition, the NJDEP is proposing registration, recordkeeping, and reporting requirements for facilities with a refrigeration system requiring 50 pounds or more of a refrigerant with high global warming potential. A “refrigeration system” includes industrial process refrigeration utilized at our nuclear facility. We continue to assess the potential impact of the NJ PACT, which could have cost implications for business operations, including the construction of new facilities or upgrades to existing utility infrastructure. Such expenditures could materially affect the continued economic viability and/or cost to construct one or more such facilities.

Table of Contents

ITEM 6.EXHIBITS

A listing of exhibits being filed with this document is as follows:

a. PSEG:
Exhibit 10(1):	Key Executive Severance Plan of Public Service Enterprise Group Incorporated, amended effective June 30, 2021
Exhibit 10(2):	Public Service Enterprise Group Incorporated 2021 Long-Term Incentive Plan effective as of April 20, 20211
Exhibit 10(3):	Public Service Enterprise Group Incorporated 2021 Equity Compensation Plan for Outside Directors effective as of April 20, 20212
Exhibit 10(4):	Agreement with Kim C. Hanemann dated May 21, 2021
Exhibit 31:	Certification by Ralph Izzo Pursuant to Rules 13a-14 and 15d-14 of the 1934 Act
Exhibit 31.1:	Certification by Daniel J. Cregg Pursuant to Rules 13a-14 and 15d-14 of the 1934 Act
Exhibit 32:	Certification by Ralph Izzo Pursuant to Section 1350 of Chapter 63 of Title 18 of the U.S. Code
Exhibit 32.1:	Certification by Daniel J. Cregg Pursuant to Section 1350 of Chapter 63 of Title 18 of the U.S. Code
Exhibit 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.
Exhibit 101.SCH:	Inline XBRL Taxonomy Extension Schema
Exhibit 101.CAL:	Inline XBRL Taxonomy Extension Calculation Linkbase
Exhibit 101.LAB:	Inline XBRL Taxonomy Extension Labels Linkbase
Exhibit 101.PRE:	Inline XBRL Taxonomy Extension Presentation Linkbase
Exhibit 101.DEF:	Inline XBRL Taxonomy Extension Definition Document
Exhibit 104:	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
b. PSE&G:
Exhibit 10(1):	Key Executive Severance Plan of Public Service Enterprise Group Incorporated, amended effective June 30, 2021
Exhibit 10(2):	Public Service Enterprise Group Incorporated 2021 Long-Term Incentive Plan effective as of April 20, 20211
Exhibit 10(3):	Public Service Enterprise Group Incorporated 2021 Equity Compensation Plan for Outside Directors effective as of April 20, 20212
Exhibit 10(4):	Agreement with Kim C. Hanemann dated May 21, 2021
Exhibit 31.2:	Certification by Ralph Izzo Pursuant to Rules 13a-14 and 15d-14 of the 1934 Act
Exhibit 31.3:	Certification by Daniel J. Cregg Pursuant to Rules 13a-14 and 15d-14 of the 1934 Act
Exhibit 32.2:	Certification by Ralph Izzo Pursuant to Section 1350 of Chapter 63 of Title 18 of the U.S. Code
Exhibit 32.3:	Certification by Daniel J. Cregg Pursuant to Section 1350 of Chapter 63 of Title 18 of the U.S. Code
Exhibit 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.
Exhibit 101.SCH:	Inline XBRL Taxonomy Extension Schema
Exhibit 101.CAL:	Inline XBRL Taxonomy Extension Calculation Linkbase
Exhibit 101.LAB:	Inline XBRL Taxonomy Extension Labels Linkbase
Exhibit 101.PRE:	Inline XBRL Taxonomy Extension Presentation Linkbase
Exhibit 101.DEF:	Inline XBRL Taxonomy Extension Definition Document
Exhibit 104:	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
c. PSEG Power:
Exhibit 10(1):	Key Executive Severance Plan of Public Service Enterprise Group Incorporated, amended effective June 30, 2021
Exhibit 10(2):	Public Service Enterprise Group Incorporated 2021 Long-Term Incentive Plan effective as of April 20, 20211
Exhibit 22:	Guaranteed Securities
Exhibit 31.4:	Certification by Ralph Izzo Pursuant to Rules 13a-14 and 15d-14 of the 1934 Act
Exhibit 31.5:	Certification by Daniel J. Cregg Pursuant to Rules 13a-14 and 15d-14 of the 1934 Act
Exhibit 32.4:	Certification by Ralph Izzo Pursuant to Section 1350 of Chapter 63 of Title 18 of the U.S. Code

Table of Contents

Exhibit 32.5:	Certification by Daniel J. Cregg Pursuant to Section 1350 of Chapter 63 of Title 18 of the U.S. Code
Exhibit 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.
Exhibit 101.SCH:	Inline XBRL Taxonomy Extension Schema
Exhibit 101.CAL:	Inline XBRL Taxonomy Extension Calculation Linkbase
Exhibit 101.LAB:	Inline XBRL Taxonomy Extension Labels Linkbase
Exhibit 101.PRE:	Inline XBRL Taxonomy Extension Presentation Linkbase
Exhibit 101.DEF:	Inline XBRL Taxonomy Extension Definition Document
Exhibit 104:	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

(1)Filed as Exhibit 99.1 with Current Report on Form 8-K, File No. 001-09120, on April 22, 2021 and incorporated herein by reference.

(2)Filed as Exhibit 4.6 to Registration Statement on Form S-8, File No. 001-09120, on April 23, 2021 and incorporated herein by reference.

Table of Contents

SIGNATURE

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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
(Registrant)
By:	/S/ ROSE M. CHERNICK
	Rose M. Chernick<br>Vice President and Controller<br>(Principal Accounting Officer)

Date: August 9, 2021

SIGNATURE

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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

PUBLIC SERVICE ELECTRIC AND GAS COMPANY
(Registrant)
By:	/S/ ROSE M. CHERNICK
	Rose M. Chernick<br>Vice President and Controller<br>(Principal Accounting Officer)

Date: August 9, 2021

SIGNATURE

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. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

PSEG POWER LLC
(Registrant)
By:	/S/ ROSE M. CHERNICK
	Rose M. Chernick<br>Vice President and Controller<br>(Principal Accounting Officer)

Date: August 9, 2021

95

Document

Exhibit 10(1)

KEY EXECUTIVE SEVERANCE PLAN OF

PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED

Amended effective June 30, 2021

ARTICLE I

PURPOSE OF THE PLAN

1.1    Purpose. The Key Executive Severance Plan of Public Service Enterprise Group Incorporated (“Plan”) is maintained by the Company to provide severance benefits to certain key executive-level employees of the Company and its affiliates whose employment is terminated under the circumstances described herein. The Plan was amended and restated effective December 17, 2012.

The Plan was amended effective January 1, 2014 to provide that (i) for Eligible Employees who become Schedule B Participants after December 31, 2013, their Change in Control benefit under Section 5.2(b) of the Plan shall be equal to two times Annual Base Salary and Target Bonus, and (ii) for Eligible Employees who become Schedule A Participants after December 31, 2013, their Change in Control benefit under Section 5.2(b) of the Plan shall be equal to 1.5 times Annual Base Salary and Target Bonus. The Plan was further amended to provide that the for purposes of determining the nonqualified plan change in control benefit under Section 5.5(a) of the Plan, with respect to Eligible Employees who become Schedule A or Schedule B Participants after December 31, 2013, their employment shall be assumed to have continued for 1.5 or 2 additional years (for Schedule A Participants and Schedule B Participants, respectively). Finally, the Plan was amended to update the Schedule A Participant list.

The Plan was amended effective June 16, 2014 to (i) add a new class of eligible Participants, Schedule C Participants, (ii) to provide that there will be no additions to Schedule B Participants, (iii) to provide that other than a current Schedule B Participant, an Eligible Employee newly hired or promoted into a position reflected on Schedule B as of June 16, 2014, shall become a Schedule A Participant, and (iv) to update the Schedule A Participant list, the Schedule B Participant list and the Schedule C Participant list.

The Plan was amended effective July 14, 2014 to update the Schedule A Participant list and the Schedule C Participant list.

The Plan was amended effective February 17, 2015 to update the Schedule A Participant list, the Schedule B Participant list and the Schedule C Participant list.

The Plan was amended effective November 18, 2015 to update the Schedule A Participant list, the Schedule B Participant list and the Schedule C Participant list, and to include the language to comply with the Securities and Exchange Commission’s whistleblower protections.

The Plan was amended effective December 15, 2015 to update the Schedule A Participant list and the Schedule C Participant list.

The Plan was amended effective July 19, 2016 to update the Schedule A Participant list and the Schedule C Participant list. The Plan was amended to comply with the Defense of Trade Secrets Act regarding the confidentiality provision. Finally, the Plan was amended

to clarify that if an Eligible Employee is newly hired or promoted into a position reflected on Schedule B as of June 16, 2014, such Eligible Employee shall become a Schedule A Participant.

The Plan was amended effective November 14, 2016 to (i) revise the definition of Cause, (ii) align the severance benefits in Article IV, (iii) align the Change in Control benefits in Article V, (iv) update the Schedule A Participant list and the Schedule C Participant list, and (v) to make administrative clarifications. The Plan is intended to comply in operation and form with Section 409A of the Internal Revenue Code of 1986, as amended (“Code”). The timing and form of payment of benefits provided under the Plan will be deemed to be automatically modified, and a Participant’s rights under the Plan will be limited so as to conform to any requirements under Section 409A of the Code.

The Plan was amended effective February 20, 2017 to update the Schedule A Participant list.

The Plan was amended effective April 17, 2017 to update the Schedule A Participant list and the Schedule C Participant list.

The Plan was amended effective July 18, 2017 (unless otherwise noted) to update the Schedule A Participant list, the Schedule B Participant list and the Schedule C Participant list.

The Plan was amended effective November 20, 2017 to update the Schedule A Participant list, the Schedule B Participant list and the Schedule C Participant list.

The Plan was amended effective July 16, 2018 to update the Schedule A Participant list and the Schedule C Participant list and to make administrative clarifications.

The Plan was amended effective November 19, 2018 to update the Schedule A Participant list.

The Plan was amended effective February 18, 2019 to update the Schedule A Participant list and the Schedule C list, and to make administrative changes.

The Plan was amended effective April 15, 2019 to (i) remove the Participant lists (Schedules A – C) from the Plan, and (ii) provide that the Participant lists will be maintained by the Chief Human Resources Officer.

The Plan was amended effective July 1, 2019 to provide that the definition of “Retirement Plan” includes Pension Plan of Public Service Enterprise Group Incorporated II and to make administrative clarifications.

The Plan is being amended effective June 30, 2021 to (i) provide that a Selectline Participant or a Benefits 2000 Participant can elect coverage under the Retiree Medical Plan upon the expiration of COBRA continuation coverage, (ii) add Appendix A which provides benefits for Eligible Employees that are involuntarily terminated as a

result of the Strategic Alternatives Review transaction(s), and (iii) provide that a Benefits 2000

Participant shall vest in their Company contributions under the Public Service Enterprise Group Incorporated Postretirement Supplemental Health Benefits Plan upon termination from employment.

ARTICLE II

DEFINITIONS

2.1 “Accrued Obligation” shall have the meaning set forth in Sections 4.2 and 5.2 of the Plan.

2.2 “Affiliate” means any corporation, trade or business if it or the Company are members of a controlled group of corporations, are under common control or are members of an affiliated service group within the meanings of Sections 414(b), 414(c) and 414(m), respectively, of the Code. The term “Affiliate” shall also include any other entity required to be aggregated with the Company pursuant to regulations under Section 414(o) of the Code.

2.3 “Annual Base Salary” means the annual rate of base salary payable to a Participant for services performed for an Employer, as in effect immediately prior to the Participant’s Date of Termination.

2.4 “Benefits 2000 Participant” means a Participant who is a participant in the Public Service Enterprise Group Incorporated Benefits 2000 Health and Welfare Benefits Plan.

2.5 “Board” means the board of directors of the Company.

2.6 “Cause” means:

(a) For purposes of Article IV and Article V:

(i) Misconduct, gross negligence, theft, or fraud against the Company, including an isolated incident that is determined by the Committee’s delegate to be material misconduct or material gross negligence;

(ii) For “Performance Reasons,” as defined in Section 2.20 of the Plan;

(iii) Material violation of the Standards of Integrity or other Company policy;

(iv) Insubordination, including an isolated incident that is determined by the Committee’s delegate to be material insubordination;

(v) One or more significant acts of dishonesty;

(vi) Any act that is likely to have the effect of injuring the reputation, business, or business relationship of, the Company, its Board of Directors, Officers, or employees, or its affiliates or subsidiaries;

(vii) Violation of any fiduciary duty, including an isolated incident that is determined by the Committee’s delegate to be a material violation;

(viii) Breach of any duty of loyalty including an isolated incident that is determined by the Committee’s delegate to be a material breach;

(ix) Any breach of the restrictive covenants contained in Exhibit I below;

(x) One or more acts of moral turpitude that constitute a violation of applicable law (included but not limited to a felony);

(xi) Conviction of a felony or plea of nolo contendere to a felony charge;

(xii) Pattern of behaviors that fail to meet the Company’s expectations described in “PSEG Values, Behaviors, and Leadership Competencies.” or

(xiii) Any other reason determined to be Cause by the Chief Executive Officer of the Company.

2.7 “Change in Control” means the occurrence of any of the following events:

(a) Any “person” (within the meaning of Section 13(d) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) is or becomes the beneficial owner within the meaning of Rule 13d-3 under the Exchange Act (a “Beneficial Owner”), directly or indirectly, of securities of the Company (not including in the securities beneficially owned by such person any securities acquired directly from the Company or its Affiliates) representing 25% or more of the combined voting power of the Company’s then outstanding securities, excluding any person who becomes such a Beneficial Owner in connection with a transaction described in clause (i) of paragraph (c) below; or

(b) The following individuals cease for any reason to constitute a majority of the number of directors of the Company then serving: individuals who, on the Effective Date, constitute the Board and any new director (other than a director whose initial assumption of office is in connection with an actual or threatened election contest, including but not limited to a consent solicitation, relating to the election of directors of the Company) whose appointment or election by the Board or nomination for election by the Company’s stockholders was approved or recommended by a vote of at least two-thirds of the directors then still in office who either were directors on the Effective Date or whose appointment, election or nomination for election was previously so approved or recommended; or

(c) There is consummated a merger or consolidation of the Company or any direct or indirect wholly-owned subsidiary of the Company with any other corporation, other than (i) a merger or consolidation which would result in the voting securities of the Company outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company or of its Affiliates, at least 75% of the combined voting power of the

securities of the Company or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or (ii) a merger or consolidation effected to implement a recapitalization of the Company (or similar transaction) in which no person is or becomes the Beneficial Owner, directly or indirectly, of securities of the Company representing 25% or more of the combined voting power of the Company’s then outstanding securities; or

(d) The shareholders of the Company approve a plan of complete liquidation or dissolution of the Company or there is consummated an agreement for the sale or disposition by the Company of all or substantially all of the Company’s assets, other than a sale or disposition by the Company of all or substantially all of the Company’s assets to an entity, at least 75% of the combined voting power of the voting securities of which are owned by stockholders of the Company in substantially the same proportions as their ownership of the Company immediately prior to such sale.

Notwithstanding the foregoing, a “Change in Control” shall not be deemed to have occurred by virtue of the consummation of any transaction or series of integrated transactions immediately following which the record holders of the common stock of the Company immediately prior to such transaction or series of transactions continue to have substantially the same proportionate ownership in an entity which owns all or substantially all of the assets of the Company immediately following such transaction or series of transactions.

2.8 “Class A Participant” means a Participant designated as a Class A Participant by the Committee.

2.9 “Class B Participant” means a Participant designated as a Class B Participant by the Committee.

2.10 “Class C Participant” means a Participant designated as a Class C Participant by the Committee.

2.11 “Code” means the Internal Revenue Code of 1986, as amended, and the regulations promulgated thereunder.

2.12 “Committee” means the Organization and Compensation Committee of the Board or any successor of such Committee.

2.13 “Company” means Public Service Enterprise Group Incorporated and any successors thereto.

2.14 “Confidential Information” means all trade secrets, proprietary and confidential business information belonging to, used by, or in the possession of the Company or any of its Affiliates, including but not limited to information, knowledge or data related to business strategies, plans and financial information, mergers, acquisitions or consolidations, purchase or sale of property, leasing, pricing, sales programs or tactics, actual or past sellers, purchasers, lessees, lessors or customers, those with whom the Company or its Affiliates has begun negotiations for new business, costs, employee compensation, marketing and development plans, inventions and technology, whether such confidential

information, knowledge or data is oral, written or electronically recorded or stored, except information in the public domain, information known by the Participant prior to employment with an Employer, and information received by the Participant from sources other than the Company or its Affiliates, without obligation of confidentiality.

2.15 “Date of Termination” means, provided that the termination constitutes a Separation from Service, (i) the date of a Participant’s death, (ii) the date on which the termination of the Participant’s employment by an Employer for Cause or without Cause, or (iii) the date on which the Participant terminates employment for Good Reason or without Good Reason, including Retirement and Disability.

2.16 “Disability” means (a) if the Participant is a participant in the Retirement Plan, the Participant is determined to be totally and permanently disabled by the Company’s medical director; or (ii) if the Participant is a participant in the Cash Balance Plan, the Participant is receiving benefits from the Company’s long-term disability plan.

2.17 “Eligible Employee” means an individual who is designated as such in accordance with Section 3.1. An Eligible Employee shall not include a “project employee.”

2.18 “Effective Date” of the amendment and restatement is June 30, 2021.

2.19 “Employer” means the Company and each Affiliate, and any successors thereto.

2.20 “Good Reason” means:

(a)    Any material reduction in the Participant’s Annual Base Salary, Target Bonus or Target Long-Term Incentive, other than reductions pursuant to a broad-based compensation reduction program or policy affecting the Participant and all similarly situated employees of the Employer. Notwithstanding the foregoing, this Subsection (a) shall not apply if the Participant moves into a position with ER&T;

(b) Any material adverse change in the Participant’s title, authority, duties, or responsibilities or the assignment to the Participant of any duties or responsibilities inconsistent in any respect with those customarily associated with the position of the Participant immediately prior to the Change in Control. Notwithstanding the foregoing, this Subsection (b) shall not apply if the Participant moves into a position with ER&T;

(c) The failure of any successor to the Company to assume this Plan in accordance with Section 11.5(b);

(d) Where the only comparable position offered to the Participant within the Employer following a Change in Control would otherwise meet the requirements of Subsections (a) and (b) of this Section 2.17 of the Plan, but would require the Participant to increase their one-way commuting distance from their principal residence by more than 50 miles; or

(e) Any other material breach of the terms of the Plan by the Company that either is not taken in good faith or, even if taken in good faith, is not remedied by the Company promptly after receipt of notice thereof from the Participant.

Notwithstanding the forgoing, for purposes of the Plan, the termination of a Participant’s employment with an Employer shall not be deemed to be for Good Reason unless such termination is effected in accordance with the following procedures. The Participant shall give the Employer a written notice (“Notice of Termination for Good Reason”) of the termination, setting forth in reasonable detail the specific acts or omissions of the Employer that constitute Good Reason and the specific provision(s) of the Plan on which the Participant relies. Unless the Committee determines otherwise, a Notice of Termination for Good Reason by the Participant must be made within 60 days after the Participant first has actual knowledge of the act or omission (or the last in a series of acts or omissions) that the Participant alleges to constitute Good Reason, and the Employer shall have 30 days from the receipt of such Notice of Termination for Good Reason to cure the conduct cited therein. A termination of employment by the Participant for Good Reason shall be effective on the final day of such 30-day cure period unless prior to such time the Employer has cured the specific conduct asserted by the Participant to constitute Good Reason to the reasonable satisfaction of the Participant.

For purposes of the Plan, a Participant’s determination that an act or failure to act constitutes Good Reason shall be presumed to be valid unless such determination is decided to be unreasonable by the Committee or its delegate pursuant to Article IX.

2.21 “Nonqualified Plan” means the Retirement Income Reinstatement Plan for Non‑Represented Employees of Public Service Enterprise Group Incorporated.

2.22 “Participant” means an Eligible Employee who has been designated by the Committee to participate in the Plan.

2.23 “Performance Reasons” means the Participant’s failure meet the expectations established for such Participant’s function in the Company as: (i) communicated to the Participant by their manager during any performance review, or (ii) may be communicated to the Participant otherwise by their manager from time to time either orally or in writing.

2.24 “Plan” means this Key Executive Severance Plan of Public Service Enterprise Group Incorporated, as set forth herein and as may be amended, modified or supplemented from time to time.

2.25 “Prior Equity Awards” means outstanding stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares and performance shares units.

2.26 “Retiree Medical Plan” means the Public Service Enterprise Group Incorporated Medical Benefits Plan for Retired Employees.

2.27 “Retirement” means a Separation from Service after the Participant has satisfied the eligibility requirements for early or normal retirement under the terms of the Retirement Plan in which the Participant participates. Notwithstanding the foregoing, for the purposes of determining benefit entitlements under Article V of the Plan,

Retirement shall not include forced retirements or any termination by an Employer without Cause or voluntary termination by the Participant for Good Reason that occurs on a date on which the Participant is Retirement eligible.

2.28 “Retirement Plan” means the retirement plan in which the Participant participates, which is either the Pension Plan of Public Service Enterprise Group Incorporated or Pension Plan of Public Service Enterprise Group Incorporated II.

2.29 “Selectline Participant” means a Participant who is a participant in the Public Service Enterprise Group Incorporated Selectline Benefits Plan.

2.30 “Separation from Service” shall be deemed to have occurred if a Participant and the Company or any Affiliate reasonably anticipates, based on the facts and circumstances, that either:

(a)    The Participant will not provide any additional services for the Company or an Affiliate after a certain date; or

(b)    The level of bona fide services performed by the Participant after a certain date will permanently decrease to no more than 50 percent of the average level of bona fide services performed by the Participant over the immediately preceding 36 months.

If a Participant is absent from employment due to military leave, sick leave or any other bona fide leave of absence authorized by the Company or an Affiliate and there is a reasonable expectation that the Participant will return to perform services for the Company or an Affiliate, a Separation from Service will not occur until the later of: (i) the first date immediately following the date that is six months after the date that the Participant was first absent from employment; or (ii) the date the Participant no longer retains a right to reemployment, to the extent the Participant retains a right to reemployment with the Company or any Affiliates under applicable law or by contract. If a Participant fails to return to work upon the expiration of any military leave, sick leave or other bona fide leave of absence where such leave is for less than six months, the Separation from Service shall occur as of the date of the expiration of such leave, unless a greater period is provided for under applicable law.

2.31 “Specified Employee” means any individual who is a key employee (as defined in Section 416(i) of the Code without regard to Section 416(i)(5) of the Code) of the Company at any time during the 12-month period ending on each December 31 (the “identification date”). If an individual is a key employee as of an identification date, the individual shall be treated as a Specified Employee for the 12-month period beginning on the April 1 following the identification date. Notwithstanding the foregoing, an individual shall not be treated as a Specified Employee unless any stock of the Company or an Affiliate is publicly traded on an established securities market or otherwise.

2.32 “Target Bonus” means the Participant’s target annual bonus, if any, under the applicable annual incentive compensation plan of the Company for the fiscal year in which the Date of Termination occurs.

2.33 “Target Long-Term Incentive” means the Participant’s target long-term incentive award, if any, under the applicable long-term incentive compensation plan of the Company.

ARTICLE III

ELIGIBILITY AND PARTICIPATION

3.1 Eligible Employees. Eligibility to participate in the Plan shall be limited to certain key executives of an Employer who (a) are not parties to individual employment or change in control agreements that provide for severance benefits, and (b) are designated, by duly adopted resolution of the Committee, as Eligible Employees.

3.2 Participation. An employee who becomes an Eligible Employee on or after January 1, 2014 shall be referred to as a Class C Participant. However, if an Eligible Employee is newly hired or promoted into one of the following positions (Chairman of the Board, President and CEO, President & COO – PSEG Power, EVP & General Counsel, EVP & CFO, PSEG, President & COO, PSE&G and COB, PSEGLI), the Eligible Employee shall be referred to as a Class A Participant. The Participant lists of Class A Participants, Class B Participants and Class C Participants shall be maintained by the Chief Human Resources Officer.

3.3 Release of Claims. Notwithstanding anything in the Plan to the contrary, payment of any benefits under the Plan is expressly contingent upon the Participant’s execution and delivery to the Company, within 30 days after the Participant’s Date of Termination, of a written agreement provided by the Company, wherein the Participant releases and discharges the Company and each of its Affiliates of any and all claims against the Company and its Affiliates related in any way to the Participant’s employment with an Employer and the termination of such employment.

3.4 Committee Discretion. The Committee shall have the sole discretion to determine eligibility for benefits under the Plan.

ARTICLE IV

SEVERANCE BENEFITS IN GENERAL

4.1    Eligible Terminations. If a Participant’s employment is involuntarily terminated by an Employer for any reason other than Cause, the Participant shall be eligible for the benefits described in this Article IV.

If a Participant terminates employment for Good Reason, other than in connection with a change in employment on account of Performance Reasons, the Participant shall be eligible for the benefits described in this Article IV.

If a Participant experiences a cessation of employment in connection with a reduction in force or an Employer reorganization (as determined by the Committee) where the only position offered to the Participant within the Company and Affiliates would require the

For the avoidance of any doubt, a Participant shall not be entitled to benefits under the Plan if termination from employment is the result of death, Disability, the Participant voluntarily terminates employment, except for Good Reason other than in connection with a change in employment on account of Performance Reasons. Also, the Participant shall not be entitled to benefits under the Plan if the Participant’s cessation of employment is in connection with the sale of the Participant’s Employer, line or unit of business of the Employer within which the Participant’s position is located, business function of the Employer within which the Participant’s position is located, or the assets related to the Employer, line or unit or business, or business function within which the Participant’s position is located, and the Participant accepts employment with the purchaser within 90 days of the closing of the transaction in a position that has an annual rate of base salary that is at least 80 percent of the Participant’s annual rate of base salary immediately prior to the closing of the sale.

If a Participant enters into a Voluntary Separation Agreement (“VSA”) with an Employer, such Participant shall not be eligible for benefits under the Plan.

4.2 Cash payment. The Company shall pay to the Participant a lump sum, in cash, the sum of (a) and (b):

(a) The Participant’s base salary through the Date of Termination to the extent not theretofore paid (hereinafter referred to as the “Accrued Obligations”); and

(b) An amount equal to the product of 1.0 times (0.5 times if the Participant were employed less than one year) the sum of the Participant’s Annual Base Salary and Target Bonus.

4.3 Long-Term Incentive Awards. The treatment of Prior Equity Awards shall be governed by the terms of the Long-Term Incentive Plan and the related award agreements.

4.4 Annual Incentive Awards. The Participant shall receive a prorated annual incentive award pursuant to the performance incentive program, if applicable, for the calendar year in which the Participant’s Termination of Employment occurs. The award shall be calculated based solely on 100 percent of the target incentive award and prorated based on the number of calendar days of employment in the calendar year in which the Participant’s termination occurs through the Participant’s Date of Termination. For purposes of this Section 4.4, calendar year shall mean 365 days.

Annual incentive awards with respect to the calendar year in which a Participant’s Date of Termination occurs will be paid at the same time as awards for such calendar year are paid to active employees of the Employer.

4.5 Outplacement Services. Outplacement services approved by the Committee, which may include individual or group counseling and administrative assistance or workshops, shall be available beginning on the Participant’s Date of Termination or such earlier

date designated by the Participant’s business unit leadership. Outplacement services shall continue to be available for the period up to 12 months and up to a maximum Company cost of $25,000.

4.6 Educational Assistance. Educational assistance shall be provided in accordance with the Employer’s tuition program.

4.7 Health Care Benefits.

(a) Medical Coverage for Selectline Participants.

(i) A Selectline Participant who has satisfied the eligibility requirements for medical coverage under the Retiree Medical Plan on the Date of Termination shall be eligible to elect coverage thereunder in accordance with the terms of the Retiree Medical Plan.

(ii) A Selectline Participant who has not otherwise satisfied the eligibility criteria for participation in the Retiree Medical Plan prior to the Date of Termination, shall be eligible to elect coverage under the Retiree Medical Plan as though such Selectline Participant has otherwise satisfied the eligibility requirements if:

(A) The Selectline Participant has attained age 50 and completed ten or more Years of Service as of the Date of Termination but the sum of the Selectline Participant’s age and Years of Service is less than 80; or

(B) The Selectline Participant has attained age 49 and completed 20 or more Years of Service as of the Date of Termination but the sum of the Selectline Participant’s age and Years of Service is less than 80.

Such coverage shall commence no earlier than the Selectline Participant’s Date of Termination. The Selectline Participant shall be charged the full cost of coverage under the Retiree Medical Plan.

(iii) If a Selectline Participant who is not eligible for, or does not elect, coverage under the Retiree Medical Plan, timely elects continuation coverage under the Consolidated Omnibus Budget Reconciliation Act of 1985, as amended (“COBRA”), the Employer shall pay the same portion of the cost of medical and/or dental coverage that it paid immediately prior to the Selectline Participant’s Date of Termination for active employees during the one-year period following the Selectline Participant’s Date of Termination. During the one-year period, the Participant shall pay the difference between the total cost of medical and/or dental coverage and the Employer’s portion of the cost. After the expiration of the one-year period, the Selectline Participant shall be charged the COBRA rate for medical and/or dental coverage for the remainder of the COBRA period. If the Participant does not timely elect COBRA medical and/or dental coverage, the Participant shall not be entitled to the benefit under this Subsection (iii). Following the one-year period, the Selectline Participant shall not be permitted to elect coverage, or be covered, under the Retiree Medical Plan. During the entire COBRA period, the Selectline Participant shall be

responsible for the full cost of COBRA vision and hearing coverage, as applicable.

(b) Medical Coverage for Benefits 2000 Participants. If a Benefits 2000 Participant who is not eligible for, or does not elect, coverage under the Retiree Plan, timely elects COBRA continuation medical and/or dental coverage, the Employer shall pay the same portion of the cost of medical and/or dental coverage that it paid immediately prior to the Participant’s Date of Termination for active employees during the one-year period following the Participant’s Date of Termination. During the one-year period, the Participant shall pay the difference between the total cost of medical and/or dental coverage and the Employer’s portion of the cost. After the expiration of the one-year period, the Benefits 2000 Participant shall be charged the COBRA rate for medical and/or dental coverage for the remainder of the COBRA period. If the Participant does not timely elect COBRA medical and/or dental coverage, the Participant shall not be entitled to the benefit under this Subsection (b). Following the one-year period, the Benefits 2000 Participant shall not be permitted to elect coverage, or be covered, under the Retiree Medical Plan. During the entire COBRA period, the Benefits 2000 Participant shall be responsible for the full cost of COBRA vision. Effective June 30, 2021, if a Benefits 2000 Participant is a participant in the Public Service Enterprise Group Incorporated Postretirement Supplemental Health Benefits Plan, they shall vest in Company contributions upon termination from employment.

(c) Effective June 30, 2021, if a Selectline Participant or a Benefits 2000 Participant timely elects COBRA continuation coverage in lieu of coverage under the Retiree Medical Plan, they may, upon the expiration of COBRA continuation coverage, elect medical coverage under the Retiree Medical Plan provided that they meet the eligibility for such coverage at time of termination.

4.8 Other Benefits. A Participant shall not be entitled to any severance, separation or early retirement incentive pay or benefits other than as provided hereunder or under any qualified or nonqualified retirement plan or deferred compensation arrangement maintained by the Employer. Except as provided in the foregoing sentence, a Participant’s rights under any other employee benefit plans maintained by the Company or an Affiliate shall be determined in accordance with the provisions of such plans, including the Company’s right to amend or terminate such plans at any time.

ARTICLE V

SEVERANCE BENEFITS AFTER A CHANGE IN CONTROL

5.1    Eligible Terminations After a Change in Control. If, within two years following the occurrence of a Change in Control, either (a) an Employer shall terminate a Participant’s employment for any reason other than for Cause, or (b) a Participant shall voluntarily terminate employment for Good Reason, the Participant shall be eligible for benefits described in this Article V of the Plan. Notwithstanding anything in the Plan to the contrary, a Participant shall not be entitled to benefits under the Plan if termination from employment is the result of death, Disability or the Participant

voluntarily terminates employment, except for Good Reason and except as otherwise provided under the Plan.

If a Participant enters into a VSA with an Employer, such Participant shall not be eligible for benefits under the Plan.

5.2 Cash Payment. The Company shall pay to the Participant, in a lump sum in cash, the aggregate of the amounts in (a) and (b) below:

(a) The sum of:

(i) The Participant’s base salary through the Date of Termination; and

(ii) The product of (x) the Participant’s Target Bonus and (y) a fraction, the numerator of which is the number of days in the current calendar year through the Date of Termination, and the denominator of which is 365;

in each case to the extent not theretofore paid (the sum of the amounts described in clauses (i) and (ii) shall be hereinafter referred to as the “Accrued Obligations”); and

(b) Either (i), (ii) or (iii):

(i) In the case of a Class A Participant, the amount equal to the product of two times the sum of the Class A Participant’s Annual Base Salary and Target Bonus;

(ii) In the case of a Class B Participant, the amount equal to the product of three times the sum of the Class B Participant’s Annual Base Salary and Target Bonus; or

(iii) In the case of a Class C Participant, the amount equal to the product of one and one-half times the sum of the Class C Participant’s Annual Base Salary and Target Bonus.

5.3 Long Term Incentive Awards. The treatment of Prior Equity Awards shall be governed by the terms of the Long-Term Incentive Plan and the related award agreements.

5.4 Health Care and Other Welfare Benefits. The Company shall pay the cost of the continued coverage of the Participant and/or the Participant’s family under the Company’s medical and dental employee benefit plans for 18 months after the Date of Termination provided that the Participant timely makes an election to continue such coverage in the Company’s medical and dental employee benefit plans under COBRA, subject to the requirements and limitations thereof. Unless otherwise limited by applicable law, thereafter, the Company shall pay the cost of the continued coverage of the Participant and/or the Participant’s family under the Company’s medical and dental employee benefit plans for an additional period of six months, in the case of a Class A Participant, or 18 months, in the case of a Class B Participant (for a Class C Participant, no additional period beyond the initial 18 months); provided however, that

if the Participant becomes re-employed with another employer and is eligible to receive medical or dental benefits under another employer provided plan, the medical and dental benefits provided by the Company under this Plan shall be secondary to those provided under such other plan during the applicable period of eligibility. If the Participant does not timely elect COBRA coverage, the Participant shall not be entitled to the COBRA continuation benefit under this Section 5.4 of the Plan.

Unless otherwise limited by applicable law or by a third-party vendor contract, for two years after the Date of Termination in the case of a Class A Participant, three years after the Date of Termination in the case of a Class B Participant, or in the case of a Class C Participant, eighteen months after the Date of Termination (or for any Participant such longer period as may be provided by the terms of the appropriate plan, program, practice or policy), the Company shall continue benefits (other than medical and dental benefits) to the Participant and/or the Participant’s family at least equal to those which would have been provided to them in accordance with the welfare plans, programs, practices and policies maintained by the Company if the Participant’s employment had not been terminated or, if more favorable to the Participant, as in effect generally at any time thereafter with respect to other peer executives of the Employer and their families.

Unless otherwise limited by applicable law or by a third-party vendor contract, the Participant’s eligibility (but not the time of commencement of such benefits) for retiree benefits pursuant to the welfare plans, programs, practices and policies maintained by the Company shall be determined as if the Participant had (A) remained employed until two years (in the case of a Class A Participant), three years (in the case of a Class B Participant), or eighteen months (in the case of a Class C Participant) after the Date of Termination and (B) retired on the last day of such period.

5.5 Nonqualified Pension Benefit. The Participant shall be paid, in a lump sum payment in cash, an amount equal to the excess of (a) – (b):

(a) The actuarial equivalent of the benefit under the Company’s applicable Retirement Plan (utilizing the rate used to determine lump sums and, to the extent applicable, other actuarial assumptions no less favorable to the Participant than those in effect under the Retirement Plan immediately prior to the Effective Date), any benefit under the Nonqualified Plan and, to the extent applicable, any other defined benefit retirement arrangement between the Participant and the Company (“Other Pension Benefits”) which the Participant would receive if the Participant’s employment continued for two, three or one and one-half additional years (for Class A Participants, Class B and Class C Participants, respectively) beyond the Date of Termination and, assuming that the Participant’s compensation for such deemed additional period was the Participant’s Annual Base Salary as in effect immediately prior to the Date of Termination and assuming a bonus in each year during such deemed additional period equal to the Target Bonus,

(b) The actuarial equivalent of the Participant’s actual benefit (paid or payable), if any, under the Retirement Plan, the Nonqualified Plan and Other Pension Benefits as of the Date of Termination (utilizing the rate used to determine lump sums and, to the extent applicable, other actuarial assumptions no less favorable to the Participant than those in effect under the Retirement Plan immediately prior to the effective date of the Change in Control).

5.6 Deferred Compensation. Any compensation previously deferred (other than pursuant to a tax-qualified plan) by or on behalf of the Participant (together with any accrued interest or earnings thereon), whether or not then vested, shall become vested on the Date of Termination and shall be paid in accordance with the terms of the applicable deferred compensation plan, policy or practice under which it was deferred to the extent permitted by Section 409A of the Code.

5.7 Outplacement Services. The Company shall, at its sole expense as incurred, provide the Participant with outplacement services suitable to the Participant’s position for a period not to exceed one year following the Date of Termination with a nationally recognized outplacement firm and up to a maximum Company cost of $25,000.

5.8 Other Benefits. To the extent not theretofore paid or provided, the Company shall pay or provide to the Participant any other amounts or benefits required to be paid or provided or which the Participant is entitled to receive under any plan, program, policy, practice, contract or agreement of the Company (or other Employer), including earned but unpaid stock and similar compensation, but excluding medical or dental benefits if the Participant is eligible for such benefits to be provided by a subsequent employer, and benefits payable under any severance plan or policy. For the one year period following the Participant’s Date of Termination, the Company will pay the cost of the Participant’s life insurance coverage.

5.9 Termination By Employer For Cause or By Participant Other Than For Good Reason. If, at any time after a Change in Control, either (a) an Employer shall terminate a participant’s employment for Cause or (b) the Participant shall voluntarily terminate employment other than for Good Reason, the Employer shall have no further payment obligations to the Participant other than for the Participant’s base salary through the Date of Termination and any accrued but unpaid vacation pay. In such case, all such amounts shall be paid to the Participant in a lump sum in accordance with Section 6.1 of the Plan.

5.10 Death. If a Participant’s employment terminates by reason of the Participant’s death after a Change in Control, all Accrued Obligations as of the time of death shall be paid to the Participant’s estate or beneficiary, as applicable, in a lump sum in cash in accordance with Section 6.1 of the Plan. The Participant’s estate or beneficiary shall be entitled to any Other Benefits in accordance with their terms. The treatment of Prior Equity Awards shall be governed by the terms of the Long-Term Incentive Plan and the related award agreements.

5.11 Disability. If a Participant’s employment is terminated by reason of Disability after a Change in Control, all Accrued Obligations shall be paid to the Participant in a lump sum in cash in accordance with Section 6.1 of the Plan. The treatment of Prior Equity Awards shall be governed by the terms of the Long-Term Incentive Plan and the related award agreements.

5.12 Retirement. If a Participant’s employment terminates as a result of Retirement after a Change in Control, the Participant shall be paid the Accrued Obligations in a lump sum in cash in accordance with Section 6.1 of the Plan and the Participant shall be entitled to any Other Benefits in accordance with their terms. The treatment of Prior Equity Awards shall be governed by the terms of the Long-Term Incentive Plan and the related award agreements.

ARTICLE VI

TIMING OF, LIMITATIONS ON AND ADJUSTMENTS TO PLAN PAYMENTS

6.1 Time of Payments. Payments under the Plan shall be made to the Participant as follows:

(a)    With respect to benefits, except those under Sections 4.4 and 5.10 of the Plan, payment to a Participant who is not a Specified Employee shall be made within the 60-day period following the Participant’s Date of Termination. However, if the period to consider and revoke the written agreement required to receive the benefits described in Articles IV and V of the Plan (i.e., the waiver and release) spans two taxable years, in all events the payments will be made in the second taxable year within 30 days following the later of the end of the first taxable year or the date the executed release is received by the Company.

(b)    With respect to benefits under Section 5.10 of the Plan, payment shall be made within the 60-day period following the Participant’s date of the Participant’s death.

(c)     With respect to benefits under Section 4.4 of the Plan, payments shall be made to the Participant at the same time the payments are made to active employees.

(d)     Notwithstanding anything to the contrary in the Plan, to the extent necessary to comply with Section 409A of the Code, payments to a Participant who is a Specified Employee shall be made within the 60-day period following the six-month anniversary of the Participant’s Date of Termination (other than by reason of death).

(e)     All payments under the Plan that are reimbursements of covered expenses incurred by the Participant shall be made within the taxable year in which the expense is incurred.

6.2 Payment Offsets. Notwithstanding anything in the Plan to the contrary, in the event a Participant is entitled to receive severance payments both under this Plan and under the terms of either (a) an individual change of control or employment agreement, (b) another severance pay plan or policy of an Employer or (c) any existing or future law or regulation, the benefits payable under this Plan shall be reduced by the amount of

any severance benefits such Participant is entitled to receive under such individual agreement, plan, policy, law or regulation.

6.3 Cap on Excess Parachute Payments; Gross-Up Payments. Notwithstanding anything in the Plan to the contrary, if (a) a Participant is a “disqualified individual” (as defined in Section 280G(c) of the Code) and (b) the severance benefits provided under Articles IV or V, as applicable, together with any other payments the Participant has the right to receive from an Employer, would constitute a “parachute payment” (as defined in Section 280G(b) of the Code) (“Parachute Payments”), the following provisions shall apply:

(a) The severance benefits under Articles IV or V shall not exceed an amount which, together with any other Parachute Payments, the Participant has a right to receive from the Employer, would be 2.99 times the Participant’s “base amount” (as defined in Section 280G of the Code) so that no portion of the amounts received by the Participant shall be subject to the excise tax imposed under Section 4999 of the Code.

(b) The determination of whether any limitation on the severance benefits payable under Articles IV or V is necessary shall be made by the Company’s independent auditor or such other certified public accounting firm as may be jointly designated by the Participant and the Company (the “Accounting Firm”), which shall provide detailed supporting calculations to the Participant and the Company. The determinations of the Accounting Firm shall be conclusive and binding on the Company and the Participant. All fees and expenses of the Accounting Firm shall be borne solely by the Company.

(c) If through error or otherwise, a Participant shall receive payments under the Plan, together with other Parachute Payments the Participant has the right to receive from an Employer, in excess of 2.99 times the Participant’s base amount, the Participant shall immediately repay the excess to the Employer upon notification from the Employer that an overpayment has been made. If the Participant fails to repay the excess to the Employer within 10 business days of the date of the Employer’s notification, the Participant will become liable to the Employer for an amount equal to two (2) times the excess amount.

6.4 Compliance with Section 409A of the Code. Notwithstanding anything in the Plan to the contrary, all Plan benefit obligations and payments are subject to Section 409A of the Code. To the extent required, the Company may modify the severance benefits payable hereunder to comply with Section 409A of the Code; provided, however, that the present value of the aggregate Plan benefits payable to a Participant after such modification shall not be less than the present value of the Plan benefits payable to the Participant prior to the modification.

6.5 Tax Withholding. Notwithstanding any other provision of this Plan, the Company may withhold from any amounts payable under this Plan such Federal, state, local, employment or foreign taxes as shall be required to be withheld pursuant to any applicable law or regulation.

ARTICLE VII

RESTRICTIVE COVENANTS

7.1 Confidentiality. As a condition to participation in the Plan, each Participant agrees to hold in a fiduciary capacity for the benefit of the Company and its Affiliates all Confidential Information which shall have been obtained by the Participant during the Participant’s employment by the Employer; except, however, that this Section 7.1 shall not apply to Confidential Information that is or becomes public knowledge, unless such Confidential Information became or becomes public knowledge due to acts of the Participant or representatives of the Participant in violation of this Section 7.1. Upon termination of the Participant’s employment, the Participant shall return to the Company all Confidential Information in their possession. After termination of the Participant’s employment with the Employer, the Participant shall not, without the prior written consent of the Company or as may otherwise be required by law or legal process, communicate or divulge any such Confidential Information to anyone other than the Company and those designated by it, except (a) otherwise publicly available information, (b) as may be necessary to enforce the Participant’s rights under the Plan or as necessary for the Participant to defend against a claim asserted directly or indirectly by the Company or its Affiliates, or (c) as may be compelled by service of a valid subpoena or other legal process (if the Participant is served with a valid subpoena or other legal process, the Participant must so notify the Company within three business days). Furthermore, nothing contained in this Plan prevents a Participant from disclosing without notice to the Company any perceived violation of law to any Federal, state, or local governmental agency or entity including, but not limited to, the Securities and Exchange Commission, or making other disclosures that are protected under the whistleblower provisions of any law. Finally, nothing in this Plan prevents a Participant – nor should a Participant be held civilly or criminally liable under any law – if the Participant discloses a trade secret: (a) in confidence to a Federal, State or local government official, either directly or indirectly, or to an attorney solely for the purpose of reporting or investigating a suspected violation of law; (b) in a complaint or other document filed in a lawsuit or other proceeding, if such filing is made under seal; (c) to the Participant’s attorney in connection with a lawsuit alleging retaliation by an employer for reporting a suspected violation of law; or (d) in connection with a lawsuit described in the immediately preceding subparagraph (c), provided the Participant: (i) files any document containing the trade secret under seal; and (ii) does not disclose the trade secret, except pursuant to a court order. Unless and until a determination has been made in accordance with Section 7.4 that the Participant has violated this Section 7.1, an asserted violation of the provisions of this Section 7.1 shall not constitute a basis for deferring or withholding any amounts otherwise payable to the Participant under the Plan.

7.2 Non-Compete. As a condition to participation in the Plan, each Participant agrees that in the event the Participant voluntarily terminates employment other than for Good Reason, for the period of one year from Date of Termination, the Participant will not, without the written consent of the Company, directly or indirectly own, manage,

operate, join, control, become employed by, consult to or participate in the ownership, management, or control of any business which is in direct competition with the Company or its Affiliates.

7.3 Non-Solicitation. As a condition to participation in the Plan, each Participant agrees that, in the event the Participant voluntarily terminates employment other than for Good Reason, for the period of one year following the Date of Termination, the Participant will not, directly or indirectly, solicit or hire, or encourage the solicitation or hiring by any employer other than the Company or its Affiliates, for any position as an employee, independent contractor, consultant or otherwise, any person who was a managerial or higher level employee of an Employer at any time during the term of the Participant’s employment by the Employer; provided, however, that this provision shall not apply with respect to the solicitation of any person after six months from the date on which such person’s employment by an Employer has terminated.

7.4 Enforcement. In the event of a breach by the Participant of any of the covenants set forth in this Article VII, it is agreed that the Company shall suffer irreparable harm for which money damages are not an adequate remedy, and that, in the event of such breach, the Company shall be entitled to obtain an order of a court of competent jurisdiction for equitable relief from such breach, including, but not limited to, temporary restraining orders and preliminary and/or permanent injunctions against the breach of such covenants by the Participant. In the event that the Company should initiate any legal action for the breach or enforcement of any of the provisions contained in this Article VII and the Company does not prevail in such action, the Company shall promptly reimburse the Participant the full amount of any court costs, filing fees, attorney’s fees which the Participant incurs in defending such action, and any loss of income during the period of such litigation.

Nothing in this Plan prohibits the Participant from reporting possible violations of Federal law or regulation to any governmental agency or entity, including but not limited to the Department of Justice, the Securities and Exchange Commission, the Congress, and any agency Inspector General, or making other disclosures that are protected under the whistleblower provisions of Federal law or regulation. The Participant does not need the prior authorization of the Law Department to make any such reports or disclosures, and is not required to notify the Company that such reports or disclosures have been made.

ARTICLE VIII

AMENDMENT AND TERMINATION

8.1 Amendment. The Company may amend this Plan at any time, and from time to time, by action of the Committee; provided, however, that no amendment adopted after the effective date of a Change in Control shall have the effect of either (a) removing an individual from the list of Participants, (b) adding conditions for participation or the entitlement to receive benefits hereunder, (c) reducing the amount of benefits payable to a Participant, or (d) otherwise restricting a Participant’s right to receive benefits

under the Plan, except as may otherwise be required to conform such payments to the requirements of Section 409A of the Code.

8.2 Termination. The Committee may terminate the Plan at any time prior to a Change in Control. The Plan may not be terminated after the effective date of a Change in Control.

ARTICLE IX

ADMINISTRATION

9.1 Plan Administrator. The Plan shall be administered by the Committee, which shall have the duties and responsibilities for administering the Plan as are specifically set forth in this Article IX.

9.2 Responsibilities of Committee.

(a)    The Committee shall have responsibility for the day to day administration of the Plan. In addition, the Committee shall have the specific powers, duties, responsibilities and obligations specifically provided for herein.

(b) Subject to the express provisions of the Plan, the Committee shall have full and exclusive authority to interpret the Plan and to make all other factual determinations deemed necessary or advisable in the implementation and administration of the Plan, including but not limited to determinations with respect to the eligibility of Participants to receive benefits under the Plan and the status and rights of such Participants and all other persons affected hereunder. The Committee’s interpretation and construction of the Plan shall be conclusive and binding on all persons.

(c) The Committee shall have sole authority to adopt rules and regulations, which shall be administered by the Committee. In addition, the Committee shall have the discretionary authority to issue rulings and interpretations concerning the Plan and all matters arising thereunder, on a uniform and nondiscriminatory basis, provided the same shall not be contrary to or inconsistent with any provision of the Plan.

(d) As a condition of distributing any benefit under the Plan, the Committee may prescribe the use of such forms and require the furnishing of such information as the Committee may deem appropriate for administering the Plan.

9.3 Allocation or Delegation of Duties and Responsibilities. In furtherance of its duties and responsibilities under the Plan, the Committee may:

(a) Employ agents to carry out non-fiduciary responsibilities;

(b)    Employ agents to carry out fiduciary responsibilities;

(c)    Consult with counsel, who may be counsel to the Company; and

(d)    Delegate any of its duties and responsibilities hereunder to such officer or officers of the Company as the Committee shall designate; except, however, that the Committee

may not delegate to any other person the designation of Eligible Employees under Section 3.1 or the authority to consider and determine appeals of alleged adverse benefit determinations.

The Committee delegates to the Chief Executive Officer of the Company the responsibility and authority to interpret the terms of the Plan, including the benefits payable thereunder. Furthermore, the Committee delegates to the Senior Vice President of Human Resources, Chief Human Resources Officer of the Company the authority to enter into a VSA with a Participant in lieu of providing benefits under the Plan.

9.4 Expenses. Unless otherwise agreed to by the Company, no person acting as a fiduciary hereunder (who is an employee of an Employer) shall receive any compensation for services as such. Expenses incurred by fiduciaries in connection with the administration of the Plan shall be paid by the Company.

9.5 Indemnification of Plan Administrator. The Company shall indemnify, to the fullest extent permitted by law, each person made or threatened to be made a party to any civil or criminal action or proceeding by reason of the fact that such person, or such person’s testator or intestate, was a member of the Committee, or a delegate of the Committee, acting in the capacity of Plan administrator.

9.6 Reliance Upon Others. The Committee, any person to whom it may delegate such of its duties and powers as provided herein, and the officers and directors of the Company shall be entitled to rely conclusively upon and shall be fully protected in any action taken by them in good faith in reliance upon any tables, valuations, certificates, opinions, reports or other advice furnished to them by any duly appointed actuary, accountant, legal counsel (who may be counsel for the Company) or other specialist.

9.7 Notification. All notices, reports and statements in connection with the Plan that are given, made, delivered or transmitted to a Participant shall be deemed duly given, made, delivered, or transmitted when mailed, by such class as the sender may deem appropriate, with postage prepaid and addressed to the Participant at the address last appearing on the records of the Employer with respect to this Plan. All notices, direct actions or other communications given, made, delivered or transmitted by a Participant to an Employer or Committee shall not be deemed to have been duly given, made, delivered, transmitted or received unless and until actually received by the Employer or Committee.

9.8 Multiple Capacities. A person may serve in more than one fiduciary capacity with respect to the Plan.

ARTICLE X

CLAIMS PROCEDURE

10.1 Submission of Claims. The initial claim by any Participant for benefits under this Plan shall be submitted in writing to the Committee (or its delegate) within 60 days after the occurrence of the termination of employment that the Participant claims to have triggered entitlement to Plan benefits.

10.2 Computation and Review of Claims. All benefits shall be computed by the Committee or its delegate. All claims shall be approved or denied by the Committee (or its delegate) as soon as practicable, but in no event later than 90 days after application by the Participant. The Committee may take an additional 90 days to review the claim, provided that the Participant is notified in writing within the initial 90-day period.

(a) Initial Denial of Claim - Any denial of a claim shall include:

(i) Reason or reasons for the denial;

(ii) Reference to pertinent Plan provisions on which the denial is based;

(iii) Description of any additional material or information necessary for the Participant to perfect the claim together with an explanation of why the material or information is necessary; and

(iv) Explanation of the Plan’s claim review procedure, described below.

(b) Review of a Denied Claim - A Participant shall have a reasonable opportunity to appeal a denied claim to the Committee (or its delegate) for a full and fair review. The Participant or a duly authorized representative shall have 60 days after receipt of written notification of the denial of claim in which to file an appeal with the Committee. The request for review shall be in writing and the Participant or a duly authorized representative shall submit written comments, documents, records and other information relating to the appeal. The Participant or a duly authorized representative may review, free of charge, pertinent Plan documents, records and other information relevant to the appeal.

(c) Committee Review - The Committee’s (or its delegate’s) review shall take into account all comments, documents, records and other information submitted by the Participant relating to the claim, without regard to whether such information was submitted or considered in the initial benefit determination.

(d) Written Decision - The Committee (or its delegate) shall issue a decision on the reviewed claim promptly but no later than 60 days after receipt of the review. The Committee may take an additional 60 days to review the claim, provided that the Participant is notified in writing within the initial 60-day period. The Committee’s decision shall be in writing and shall include:

(i) Reasons for the decision;

(ii) References to the Plan provisions on which the decision is based;

(iii) Statement that the Participant is entitled to receive, upon request, reasonable access to, and copies of, all documents, records and other information relevant to the claim; and

(iv) Statement that the Participant is entitled to bring a civil suit under Section 502(a) of ERISA.

(e) Binding Effect - The Committee’s (or its delegate’s) decision shall be final and binding on the Participant and the Employer.

ARTICLE XI

GENERAL PROVISIONS

11.1 Construction. This Plan shall be construed and enforced in accordance with and governed by the internal substantive laws (and not the laws relating to conflict of laws or choice of laws) of the State of New Jersey, except to the extent that such laws are preempted by Federal law.

11.2 Unfunded Plan. The obligations of the Company under this Plan are not required to be funded in advance. Nothing contained in this Plan shall give an Eligible Employee or Participant any right, title or interest in any property of the Company or any of its Affiliates.

11.3 No Right to Continued Employment. Nothing contained herein shall be deemed to give any Eligible Employee or Participant the right to be retained in the employment of an Employer or to limit the rights of any Employer to discharge any Eligible Employee or Participant at any time, with or without notice and with or without Cause.

11.4 Partial Invalidity. The invalidity or unenforceability of any term or provision, or any clause, or portion thereof, of this Plan shall in no way impair or affect the validity or enforceability of any other provision of this Plan, which shall remain in full force and effect.

11.5 Successors and Assigns.

(a) This Plan shall inure to the benefit of and be binding upon the Company and its successors and assigns.

(b) The Company shall require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of the Company to assume expressly and agree to perform the Company’s obligations under the Plan in the same manner and to the same extent that the Company would be required to perform it if no such succession had taken place.

(c) In no event shall a Participant assign their interests under the Plan to any other person without the prior written consent of the Committee.

11.6 Waivers. Failure to strictly comply with any term, condition or requirement set forth in the Plan shall not be deemed a waiver of such term, condition or requirement, nor shall any waiver of any such term, condition or requirement at any one time or times be deemed to result in a waiver of such term, condition or requirement at any other time or times.

11.7 Gender and Number. The singular shall include the plural, unless indicated otherwise by the context.

11.8 Headings. The headings of the Plan are for purposes of reference only and shall not limit or otherwise affect the meaning hereof.

* * *

/s/ Sheila J. Rostiac _____06/30/2021

Signature Date

APPENDIX A

This Appendix A is effective June 30, 2021 and shall apply to Transaction Participants. Unless otherwise explicitly stated in this Appendix A, the other provisions of the Plan shall apply. This Appendix A shall self-expire 60 days after the last event of the Transaction.

Section 1 Definitions

1.1    Benefits 2000 Transaction Participant – a Transaction Participant who is eligible for benefits under the Public Service Enterprise Group Incorporated Benefits 2000 Health and Welfare Benefits Plan.

1.2    Impacted Employee – an Eligible Employee as defined in Section 3.1 of the Plan whose employment is terminated as a result of the Transaction.

1.3    Selectline Transaction Participant – a Transaction Participant who is eligible for benefits under the Public Service Enterprise Group Incorporated Selectline Benefits Plan.

1.4    Transaction – strategic alternatives review transactions for PSEG Power’s non-nuclear generating fleet, which includes more than 6,750 megawatts of fossil generation located in New Jersey, Connecticut, New York and Maryland, as well as the 467 megawatt Solar Source portfolio located in various states.

1.5    Transaction Participant – an Impacted Employee who is eligible for benefits under this Appendix A, subject to Section 2 below.

Section 2 Eligibility

2.1 Impacted Employees.

(a) Subject to Section 2.1(b) below, an Impacted Employee shall be eligible for benefits under this Appendix A.

(b) An Impacted Employee shall not be eligible for benefits under the Plan, including this Appendix A, if, as determined by the Plan Administrator, in its sole discretion:

(i) They are involuntary terminated for cause (as determined by the Plan Administrator),

(ii) Their termination of employment is the result of death or Disability;

(iii) They voluntary terminate employment;

(iv) They enter into VSA with an Employer; or

(v) They accept and start at a another position with an Employer.

Section 3 Severance Benefits

For the avoidance of any doubt, Section 3 of this Appendix A shall apply to Transaction Participants and Section 4 of the Plan shall not apply unless otherwise specifically stated herein.

3.1 Severance Pay. The Transaction Participant shall receive the severance pay as provided for in Section 4.2 of the Plan.

3.2 Health Coverage. Section 4.8 of the Plan shall apply to Transaction Participants.

3.3 Annual Incentive Award. Section 4.4 of the Plan shall apply, except that the pro-rated incentive shall be based on actual results and paid at the same that incentive awards are paid to similarly situated active employees.

3.3 Equity Awards. The treatment of equity awards shall be governed under the terms of the award agreement.

3.4 Educational Assistance. Education assistance shall be provided in accordance with the Employer’s tuition program.

3.5 Outplacement. The Transaction Participant shall be provided with outplacement services as provided for in Section 4.5 of the Plan.

3.6 Pension and Retiree Health Milestones. A Selectline Transaction Participant shall receive up to an additional twelve (12) months of age and/or service credit solely for purposes of (i) satisfying the requirements for the Rule of 80 or eligibility for an unreduced benefit under the Pension Plan, and/or (ii) determining eligibility for benefits under the Retiree Medical Plan, the Public Service Enterprise Group Incorporated Dental Benefits Plan for Retired Employees, and the Public Service Enterprise Group Incorporated Group Term Life Insurance Plan for Retired Employees (collectively, “Retiree Plans”), as further described under the Pension Plan and the Retiree Plans. For the avoidance of any doubt, a Selectline Transaction Participant shall not receive additional age or service credit for purposes of benefit accruals and/or determining the amount of the company’s subsidy under the Retiree Plans.

A Benefits 2000 Transaction Participant shall receive up to an additional twelve (12) months of age and/or service credit solely for purposes of satisfying the eligibility requirements for benefits under the Retiree Medical Plan as further described in the Retiree Medical Plan. For the avoidance of any doubt, a Benefits 2000 Transaction Participant is responsible for the full cost of coverage and shall not receive additional age or service credit for purposes of benefit accruals and/or determining the amount of the company’s subsidy under the Retiree Plans.

3.8 COBRA/Retiree Medical. A Transaction Participant who timely elects COBRA continuation coverage in lieu of coverage under the Retiree Medical Plan and the Retiree Dental Plan, may, upon the expiration of COBRA continuation coverage, elect medical coverage under the Retiree Medical Plan and/or dental coverage Retiree Dental Plan provided that they meet the eligibility for such coverage at time of termination.

3.9 Waiver and Release of Claims. A Transaction Participant shall not be entitled to the benefits described in this Appendix A unless, by the later of their Termination Date, or the date that is specified in the Waiver and Release after the Transaction Participant is provided the Waiver and Release, they sign and submit to the Plan Administrator’s delegate the Waiver and Release. A Transaction Participant may revoke such Waiver and Release by notifying the Plan Administrator’s delegate of such revocation in writing at any time prior to the eighth day after such Waiver and Release is signed. A Transaction Participant who does not submit to the Plan Administrator’s delegate a signed Waiver and Release or who revokes a Waiver and Release that has been submitted shall not be entitled to any of the benefits under this Appendix A.

3.10 Reemployment. If the Waiver and Release does not provide that a Transaction Participant is prohibited from seeking reemployment from an Company or one of its subsidiaries, nothing in this Plan or Appendix A shall prohibit a Transaction Participant from applying for such reemployment.

3.11 VEBA. A Transaction Participant shall vest in their Company contributions under the Public Service Enterprise Group Incorporated Postretirement Supplemental Health Benefits Plan upon termination from employment.

3.12 Other Benefits. Section 4.8 of the Plan shall apply to Transaction Participants.

3.13 Termination Date. A Transaction Participant shall be eligible for severance benefits under this Section A provided that they remained continuously employed by the Employer through the earlier of (i) the closing of the Transaction, or (ii) the Employer releases the Transaction Participant.

26

Document

Exhibit 10(4)

Sheila J. Rostiac	Human Resources
Senior Vice President - Human Resources	80 Park Plaza T4, Newark, NJ 07102
Chief Human Resources Officer & Chief Diversity Officer	tel: 973-430-6047
	email: sheila.rostiac@pseg.com

May 21, 2021

Kim C. Hanemann

In Care Of PSEG

Dear Kim:

I am pleased to offer you the position of President & Chief Operating Officer, PSE&G, effective June 30, 2021. In this position, you will be paid a base annual salary of $630,000. You shall be eligible for your next salary review in January 2022. Salary reviews will be conducted annually thereafter.

You will continue to be eligible to participate in PSEG’s Senior Management Incentive Compensation Plan (“SMICP”) under the terms and conditions of the SMICP. Your target incentive award in this position for 2021 will be 75% of your base salary, however, you may be eligible to receive up to 150% of your base salary dependent upon business results. Targets and awards may be adjusted from time to time in accordance with established plan procedures. There is no guarantee of payment under the SMICP, and any such payment will be contingent upon your establishment and successful completion of goals and objectives. Your award under the SMICP, if earned, will be based upon the successful completion of goals and objectives for 2021 and payable in 2022. Any SMICP award for 2021 will be prorated based on your promotion date of June 30, 2021. Your award, if earned, will be prorated between your former position, salary, and target of 65% in the SMICP through June 2021 and your new position, salary and target of 75% in the SMICP for the remainder of the year.

You will continue to be a participant in the PSEG Long-Term Incentive Plan (“LTIP”). It was recommended and approved by the Organization Compensation Committee (“O&CC”) that you be provided with a supplemental 2021 LTIP grant in the amount of $325,000. This will be in the form of 30% Restricted Stock Units (“RSUs”) and 70% Performance Share Units (“PSUs”). Future LTIP grants will be in the form of 30% as RSUs and 70% as PSUs. The number and form of LTIP grants recommended in any given year will appropriately reflect your responsibilities and ability to contribute to the long-term success of PSEG and is subject to the approval of the O&CC of the Board. All future grants under the LTIP will be subject to the terms of the LTIP and the related grant award agreements.

You will continue to be eligible to participate in the PSEG Equity Deferral Plan (“Deferred Equity Plan”), which allows you to defer all or a portion of the receipt of shares under the LTIP. If you would like to defer all or a portion of your 2021 supplemental RSUs and/or PSUs under this plan you must make your elections on-line at Fidelity NetBenefits by July 30, 2021.

Kim C. Hanemann                                May 21, 2021

If, at the time you terminate from employment, you are determined to be a “specified employee” as defined in Section 409A of the Internal Revenue Code of 1986, as amended (“Section 409A”), your nonqualified deferred compensation payments will be delayed for six months following your termination of employment to the extent necessary to satisfy Section 409A.

You will continue to be a Schedule A participant in the Key Executive Severance Plan of Public Service Enterprise Group Incorporated, as amended from time to time.

You will continue to be required to own and retain a level of company stock commensurate with your new position as outlined in the attached “Officer Stock Ownership and Retention Policy”. Please note the required minimum level of company stock ownership will be 4x base salary for this position.

The company will continue to provide you with a monthly stipend in the amount of $1,000 for the purchase or lease of a vehicle along with associated costs such as vehicle maintenance, mileage and insurance. This stipend may be amended from time to time by the Company.

You will be required to complete the attached FERC/BPU interlock questionnaire and your position is contingent upon successful clearance of interlock requirements.

Finally, you will be required to sign the enclosed Confidentiality, Non-Competition, and Non-Solicitation Agreement, and the enclosed Arbitration Agreement.

At all times, your employment with PSEG is and will be considered at-will, which means that either you or the Company is free to terminate the employment relationship at any time, for any reason, with or without cause.

This letter shall not be construed, nor is it intended to be construed, as a binding contract of employment.

Additionally, a booklet referencing the Responsibilities of Corporate Officers and Directors will be mailed separately to you at your home address.

If the foregoing is in accordance with your understanding, please sign this letter and the enclosed Agreements, and return them to me.

Kim C. Hanemann                                May 21, 2021

Sincerely,

/s/ Sheila J. Rostiac

Sheila J. Rostiac

Senior Vice President – Human Resources

and Chief Human Resources Officer and Chief

Diversity Officer

Agreed to this_21_ day of May, 2021.

/s/ Kim C. Hanemann

_______________________________________

Kim C. Hanemann

Attachments:

1.Senior Management Incentive Compensation Plan (“SMICP”)

2.Key Executive Severance Plan of Public Service Enterprise Group, Inc.

3.PSEG Equity Deferral Plan

4.Officer Stock Ownership & Retention Policy

5.FERC/BPU Interlock Questionnaire

6.Arbitration Agreement

7.Confidentiality, Non-Competition and Non-Solicitation Agreement

8.Responsibilities of Corporate Officers and Directors

3

Document

EXHIBIT 22

The following wholly owned subsidiaries of PSEG Power LLC have fully and unconditionally guaranteed all Senior Notes issued by PSEG Power LLC on a joint and several basis.

Name	State of Incorporation
PSEG Fossil LLC	Delaware
PSEG Nuclear LLC	Delaware
PSEG Energy Resources & Trade LLC	Delaware

Document

EXHIBIT 31

Certification Pursuant to Rules 13a-14 and 15d-14

of the 1934 Securities Exchange Act

I, Ralph Izzo, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Public Service Enterprise Group Incorporated;

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 officer(s) 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 officer(s) 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.

Date:	August 9, 2021	/s/ Ralph Izzo
		Ralph Izzo
		Public Service Enterprise Group Incorporated
		Chief Executive Officer

Document

EXHIBIT 31.1

Certification Pursuant to Rules 13a-14 and 15d-14

of the 1934 Securities Exchange Act

I, Daniel J. Cregg, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Public Service Enterprise Group Incorporated;

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 officer(s) 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 officer(s) 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.

Date:	August 9, 2021	/s/ Daniel J. Cregg
		Daniel J. Cregg
		Public Service Enterprise Group Incorporated
		Chief Financial Officer

Document

EXHIBIT 31.2

Certification Pursuant to Rules 13a-14 and 15d-14

of the 1934 Securities Exchange Act

I, Ralph Izzo, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Public Service Electric and Gas Company;

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 officer(s) 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 officer(s) 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.

Date:	August 9, 2021	/s/ Ralph Izzo
		Ralph Izzo
		Public Service Electric and Gas Company
		Chief Executive Officer

Document

EXHIBIT 31.3

Certification Pursuant to Rules 13a-14 and 15d-14

of the 1934 Securities Exchange Act

I, Daniel J. Cregg, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Public Service Electric and Gas Company;

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 officer(s) 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 officer(s) 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.

Date:	August 9, 2021	/s/ Daniel J. Cregg
		Daniel J. Cregg
		Public Service Electric and Gas Company
		Chief Financial Officer

Document

EXHIBIT 31.4

Certification Pursuant to Rules 13a-14 and 15d-14

of the 1934 Securities Exchange Act

I, Ralph Izzo, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of PSEG Power LLC;

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

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

4.The registrant’s other certifying officer(s) 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 officer(s) 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.

Date:	August 9, 2021	/s/ Ralph Izzo
		Ralph Izzo
		PSEG Power LLC
		Chief Executive Officer

Document

EXHIBIT 31.5

Certification Pursuant to Rules 13a-14 and 15d-14

of the 1934 Securities Exchange Act

I, Daniel J. Cregg, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of PSEG Power LLC;

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

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

4.The registrant’s other certifying officer(s) 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 officer(s) 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.

Date:	August 9, 2021	/s/ Daniel J. Cregg
		Daniel J. Cregg
		PSEG Power LLC
		Chief Financial Officer

Document

EXHIBIT 32

Certification Pursuant to Section 1350 of Chapter 63 of Title 18

of the United States Code

I, Ralph Izzo, Chief Executive Officer of Public Service Enterprise Group Incorporated, to the best of my knowledge, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that (i) the Quarterly Report of Public Service Enterprise Group Incorporated on Form 10-Q for the quarter ended June 30, 2021 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Public Service Enterprise Group Incorporated.

/s/ Ralph Izzo
Ralph Izzo
Public Service Enterprise Group Incorporated
Chief Executive Officer
August 9, 2021

Document

EXHIBIT 32.1

Certification Pursuant to Section 1350 of Chapter 63 of Title 18

of the United States Code

I, Daniel J. Cregg, Chief Financial Officer of Public Service Enterprise Group Incorporated, to the best of my knowledge, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that (i) the Quarterly Report of Public Service Enterprise Group Incorporated on Form 10-Q for the quarter ended June 30, 2021 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Public Service Enterprise Group Incorporated.

/s/ Daniel J. Cregg
Daniel J. Cregg
Public Service Enterprise Group Incorporated
Chief Financial Officer
August 9, 2021

Document

EXHIBIT 32.2

Certification Pursuant to Section 1350 of Chapter 63 of Title 18

of the United States Code

I, Ralph Izzo, Chief Executive Officer of Public Service Electric and Gas Company, to the best of my knowledge, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that (i) the Quarterly Report of Public Service Electric and Gas Company on Form 10-Q for the quarter ended June 30, 2021 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Public Service Electric and Gas Company.

/s/ Ralph Izzo
Ralph Izzo
Public Service Electric and Gas Company
Chief Executive Officer
August 9, 2021

Document

EXHIBIT 32.3

Certification Pursuant to Section 1350 of Chapter 63 of Title 18

of the United States Code

I, Daniel J. Cregg, Chief Financial Officer of Public Service Electric and Gas Company, to the best of my knowledge, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that (i) the Quarterly Report of Public Service Electric and Gas Company on Form 10-Q for the quarter ended June 30, 2021 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Public Service Electric and Gas Company.

/s/ Daniel J. Cregg
Daniel J. Cregg
Public Service Electric and Gas Company
Chief Financial Officer
August 9, 2021

Document

EXHIBIT 32.4

Certification Pursuant to Section 1350 of Chapter 63 of Title 18

of the United States Code

I, Ralph Izzo, Chief Executive Officer of PSEG Power LLC, to the best of my knowledge, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that (i) the Quarterly Report of PSEG Power LLC on Form 10-Q for the quarter ended June 30, 2021 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of PSEG Power LLC.

/s/ Ralph Izzo
Ralph Izzo
PSEG Power LLC
Chief Executive Officer
August 9, 2021

Document

EXHIBIT 32.5

Certification Pursuant to Section 1350 of Chapter 63 of Title 18

of the United States Code

I, Daniel J. Cregg, Chief Financial Officer of PSEG Power LLC, to the best of my knowledge, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that (i) the Quarterly Report of PSEG Power LLC on Form 10-Q for the quarter ended June 30, 2021 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended and (ii) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of PSEG Power LLC.

/s/ Daniel J. Cregg
Daniel J. Cregg
PSEG Power LLC
Chief Financial Officer
August 9, 2021