10-Q 1 pseg-3312019q110xq.htm 10-Q
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)
ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED March 31, 2019
OR
¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
FOR THE TRANSITION PERIOD FROM TO

Commission File Number |  | Registrants, State of Incorporation, Address, and Telephone Number |  | I.R.S. Employer Identification No.
001-09120 |  | PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED (A New Jersey Corporation) 80 Park Plaza Newark, New Jersey 07102 973 430-7000 |  | 22-2625848
001-00973 |  | PUBLIC SERVICE ELECTRIC AND GAS COMPANY (A New Jersey Corporation) 80 Park Plaza Newark, New Jersey 07102 973 430-7000 |  | 22-1212800
001-34232 |  | PSEG POWER LLC (A Delaware Limited Liability Company) 80 Park Plaza Newark, New Jersey 07102 973 430-7000 |  | 22-3663480

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 ý 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 ý No ¨
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 x | Accelerated filer o | Non-accelerated filer o | Smaller reporting company o | Emerging growth company o
Public Service Electric and Gas Company | Large accelerated filer o | Accelerated filer o | Non-accelerated filer x | Smaller reporting company o | Emerging growth company o
PSEG Power LLC | Large accelerated filer o | Accelerated filer o | Non-accelerated filer x | Smaller reporting company o | Emerging growth company o

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

Registrant |  | Title of Each Class |  | Trading Symbol(s) |  | Name of Each Exchange On Which Registered
Public Service Enterprise Group Incorporated |  | Common Stock without par value |  | PEG |  | New York Stock Exchange
|  | First and Refunding Mortgage Bonds |  |  |  |
Public Service Electric and Gas Company |  | 9 1/4% Series CC, due 2021 |  | PEG21 |  | New York Stock Exchange
| 8%, due 2037 |  | PEG37D |  | New York Stock Exchange
|  | 5%, due 2037 |  | PEG37J |  | New York Stock Exchange
PSEG Power LLC |  | 8 5/8% Senior Notes, due 2031 |  | PEG31 |  | New York Stock Exchange

As of April 16, 2019, Public Service Enterprise Group Incorporated had outstanding 505,430,473 shares of its sole class of Common Stock, without par value.
As of April 16, 2019, 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.

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|  | 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 | 26
| Note 5. Variable Interest Entity (VIE) | 27
| Note 6. Rate Filings | 27
| Note 7. Leases | 27
| Note 8. Financing Receivables | 31
| Note 9. Trust Investments | 33
| Note 10. Pension and Other Postretirement Benefits (OPEB) | 38
| Note 11. Commitments and Contingent Liabilities | 40
| Note 12. Debt and Credit Facilities | 47
| Note 13. Financial Risk Management Activities | 48
| Note 14. Fair Value Measurements | 52
| Note 15. Other Income (Deductions) | 58
| Note 16. Income Taxes | 59
| Note 17. Accumulated Other Comprehensive Income (Loss), Net of Tax | 60
| Note 18. Earnings Per Share (EPS) and Dividends | 64
| Note 19. Financial Information by Business Segment | 65
| Note 20. Related-Party Transactions | 65
| Note 21. Guarantees of Debt | 67
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 69
| Executive Overview of 2019 and Future Outlook | 69
| Results of Operations | 76
| Liquidity and Capital Resources | 79
| Capital Requirements | 81
| Accounting Matters | 81
Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 81
Item 4. | Controls and Procedures | 82
PART II. OTHER INFORMATION |
Item 1. | Legal Proceedings | 83
Item 1A. | Risk Factors | 83
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 83
Item 5. | Other Information | 83
Item 6. | Exhibits | 85
| Signatures | 86

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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:

• | 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;

• | any inability to manage our energy obligations with available supply;

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

• | increases in competition in wholesale energy and capacity markets;

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

• | economic downturns;

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

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

• | changes in state and federal legislation and regulations, and PSE&G’s ability to recover costs and earn returns on authorized investments;

• | the impact of any future rate proceedings;

• | 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;

• | the impact on our New Jersey nuclear plants if such plants are not selected to participate in future Zero Emission Certificate (ZEC) programs or if adverse changes are made to the capacity market construc t;

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

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

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

• | adverse outcomes of any legal, regulatory or other proceeding, settlement, investigation or claim applicable to us and/or the energy industry;

• | changes in tax laws and regulations;

• | the impact of our holding company structure on our ability to meet our corporate funding needs, service debt and pay dividends;

• | lack of growth or slower growth in the number of customers or changes in customer demand;

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

• | reliance on transmission facilities that we do not own or control and the impact on our ability to maintain adequate transmission capacity;

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

• | any equipment failures, accidents, severe weather events or other incidents that impact our ability to provide safe and reliable service to our customers;

• | our inability to exercise control over the operations of generation facilities in which we do not maintain a controlling interest;

• | any inability to recover the carrying amount of our long-lived assets and leveraged leases;

• | any inability to maintain sufficient liquidity;

• | any inability to realize anticipated tax benefits or retain tax credits;

• | challenges associated with recruitment and/or retention of key executives and a qualified workforce;

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

• | the impact of acts of terrorism, cybersecurity attacks or intrusions.

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 (Power). Information relating to any individual company is filed by such company on its own behalf. PSE&G and 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 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.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
Millions, except per share data
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| OPERATING REVENUES | $ | 2,980 |  |  | $ | 2,818 |  |
| OPERATING EXPENSES |  |  |  |
| Energy Costs | 1,124 |  |  | 952 |  |
| Operation and Maintenance | 756 |  |  | 754 |  |
| Depreciation and Amortization | 314 |  |  | 280 |  |
| Total Operating Expenses | 2,194 |  |  | 1,986 |  |
| OPERATING INCOME | 786 |  |  | 832 |  |
| Income from Equity Method Investments | 2 |  |  | 2 |  |
| Net Gains (Losses) on Trust Investments | 128 |  |  | (22 | ) |
| Other Income (Deductions) | 33 |  |  | 32 |  |
| Non-Operating Pension and OPEB Credits (Costs) | 33 |  |  | 19 |  |
| Interest Expense | (133 | ) |  | (103 | ) |
| INCOME BEFORE INCOME TAXES | 849 |  |  | 760 |  |
| Income Tax Benefit (Expense) | (149 | ) |  | (202 | ) |
| NET INCOME | $ | 700 |  |  | $ | 558 |  |
| WEIGHTED AVERAGE COMMON SHARES OUTSTANDING: |  |  |  |
| BASIC | 504 |  |  | 504 |  |
| DILUTED | 507 |  |  | 507 |  |
| NET INCOME PER SHARE: |  |  |  |
| BASIC | $ | 1.39 |  |  | $ | 1.11 |  |
| DILUTED | $ | 1.38 |  |  | $ | 1.10 |  |

See Notes to Condensed Consolidated Financial Statements.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| NET INCOME | $ | 700 |  |  | $ | 558 |  |
| Other Comprehensive Income (Loss), net of tax |  |  |  |
| Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit of $(13) and $9 for 2019 and 2018, respectively | 21 |  |  | (14 | ) |
| Unrealized Gains (Losses) on Cash Flow Hedges, net of tax (expense) benefit of $1 and $0 for 2019 and 2018, respectively | (4 | ) |  | — |  |
| Pension/Other Postretirement Benefit Costs (OPEB) adjustment, net of tax (expense) benefit of $(4) and $(3) for 2019 and 2018, respectively | — |  |  | 8 |  |
| Other Comprehensive Income (Loss), net of tax | 17 |  |  | (6 | ) |
| COMPREHENSIVE INCOME | $ | 717 |  |  | $ | 552 |  |

See Notes to Condensed Consolidated Financial Statements.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONDENSED CONSOLIDATED BALANCE SHEETS
Millions
(Unaudited)

|  | March 31, 2019 |  | December 31, 2018 |
| ASSETS |
| CURRENT ASSETS |  |  |  |
| Cash and Cash Equivalents | $ | 65 |  |  | $ | 177 |  |
| Accounts Receivable, net of allowances of $72 in 2019 and $63 in 2018 | 1,454 |  |  | 1,435 |  |
| Tax Receivable | 149 |  |  | 242 |  |
| Unbilled Revenues | 188 |  |  | 240 |  |
| Fuel | 134 |  |  | 331 |  |
| Materials and Supplies, net | 584 |  |  | 571 |  |
| Prepayments | 112 |  |  | 94 |  |
| Derivative Contracts | 20 |  |  | 11 |  |
| Regulatory Assets | 294 |  |  | 389 |  |
| Other | 27 |  |  | 17 |  |
| Total Current Assets | 3,027 |  |  | 3,507 |  |
| PROPERTY, PLANT AND EQUIPMENT | 44,854 |  |  | 44,201 |  |
| Less: Accumulated Depreciation and Amortization | (10,067 | ) |  | (9,838 | ) |
| Net Property, Plant and Equipment | 34,787 |  |  | 34,363 |  |
| NONCURRENT ASSETS |  |  |  |
| Regulatory Assets | 3,423 |  |  | 3,399 |  |
| Operating Lease Right-of-Use Assets | 253 |  |  | — |  |
| Long-Term Investments | 906 |  |  | 896 |  |
| Nuclear Decommissioning Trust (NDT) Fund | 2,049 |  |  | 1,878 |  |
| Long-Term Receivable of Variable Interest Entity (VIE) | 631 |  |  | 624 |  |
| Rabbi Trust Fund | 233 |  |  | 224 |  |
| Goodwill | 16 |  |  | 16 |  |
| Other Intangibles | 156 |  |  | 143 |  |
| Derivative Contracts | 4 |  |  | 1 |  |
| Other | 271 |  |  | 275 |  |
| Total Noncurrent Assets | 7,942 |  |  | 7,456 |  |
| TOTAL ASSETS | $ | 45,756 |  |  | $ | 45,326 |  |

See Notes to Condensed Consolidated Financial Statements.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONDENSED CONSOLIDATED BALANCE SHEETS
Millions
(Unaudited)

|  | March 31, 2019 |  | December 31, 2018 |
| LIABILITIES AND CAPITALIZATION |
| CURRENT LIABILITIES |  |  |  |
| Long-Term Debt Due Within One Year | $ | 900 |  |  | $ | 1,294 |  |
| Commercial Paper and Loans | 1,151 |  |  | 1,016 |  |
| Accounts Payable | 1,135 |  |  | 1,451 |  |
| Derivative Contracts | 13 |  |  | 11 |  |
| Accrued Interest | 158 |  |  | 110 |  |
| Accrued Taxes | 73 |  |  | 26 |  |
| Clean Energy Program | 85 |  |  | 143 |  |
| Obligation to Return Cash Collateral | 129 |  |  | 136 |  |
| Regulatory Liabilities | 320 |  |  | 311 |  |
| Other | 509 |  |  | 437 |  |
| Total Current Liabilities | 4,473 |  |  | 4,935 |  |
| NONCURRENT LIABILITIES |  |  |  |
| Deferred Income Taxes and Investment Tax Credits (ITC) | 5,929 |  |  | 5,713 |  |
| Regulatory Liabilities | 3,148 |  |  | 3,221 |  |
| Operating Leases | 250 |  |  | — |  |
| Asset Retirement Obligations | 1,067 |  |  | 1,063 |  |
| OPEB Costs | 698 |  |  | 704 |  |
| OPEB Costs of Servco | 509 |  |  | 501 |  |
| Accrued Pension Costs | 778 |  |  | 791 |  |
| Accrued Pension Costs of Servco | 108 |  |  | 109 |  |
| Environmental Costs | 364 |  |  | 327 |  |
| Derivative Contracts | 7 |  |  | 4 |  |
| Long-Term Accrued Taxes | 189 |  |  | 181 |  |
| Other | 206 |  |  | 232 |  |
| Total Noncurrent Liabilities | 13,253 |  |  | 12,846 |  |
| COMMITMENTS AND CONTINGENT LIABILITIES (See Note 11) |  |  |  |  |  |
| CAPITALIZATION |  |  |  |
| LONG-TERM DEBT | 13,216 |  |  | 13,168 |  |
| STOCKHOLDERS’ EQUITY |  |  |  |
| Common Stock, no par, authorized 1,000 shares; issued, 2019 and 2018—534 shares | 4,969 |  |  | 4,980 |  |
| Treasury Stock, at cost, 2019 and 2018—30 shares | (839 | ) |  | (808 | ) |
| Retained Earnings | 11,125 |  |  | 10,582 |  |
| Accumulated Other Comprehensive Loss | (441 | ) |  | (377 | ) |
| Total Stockholders’ Equity | 14,814 |  |  | 14,377 |  |
| Total Capitalization | 28,030 |  |  | 27,545 |  |
| TOTAL LIABILITIES AND CAPITALIZATION | $ | 45,756 |  |  | $ | 45,326 |  |

See Notes to Condensed Consolidated Financial Statements.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |
| Net Income | $ | 700 |  |  | $ | 558 |  |
| Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: |  |  |  |
| Depreciation and Amortization | 314 |  |  | 280 |  |
| Amortization of Nuclear Fuel | 47 |  |  | 50 |  |
| Emission Allowances and Renewable Energy Credit (REC) Compliance Accrual | 24 |  |  | 24 |  |
| Provision for Deferred Income Taxes (Other than Leases) and ITC | 102 |  |  | 76 |  |
| Non-Cash Employee Benefit Plan (Credits) Costs | (3 | ) |  | 17 |  |
| Leveraged Lease (Income) Loss, Adjusted for Rents Received and Deferred Taxes | (1 | ) |  | 4 |  |
| Net Realized and Unrealized (Gains) Losses on Energy Contracts and Other Derivatives | (109 | ) |  | (119 | ) |
| Net Change in Regulatory Assets and Liabilities | 69 |  |  | (6 | ) |
| Cost of Removal | (30 | ) |  | (38 | ) |
| Net (Gains) Losses and (Income) Expense from NDT Fund | (137 | ) |  | 12 |  |
| Net Change in Certain Current Assets and Liabilities: |  |  |  |
| Tax Receivable | 77 |  |  | 6 |  |
| Accrued Taxes | 26 |  |  | 125 |  |
| Margin Deposit | 190 |  |  | 25 |  |
| Other Current Assets and Liabilities | (67 | ) |  | 160 |  |
| Employee Benefit Plan Funding and Related Payments | (14 | ) |  | (36 | ) |
| Other | 30 |  |  | 2 |  |
| Net Cash Provided By (Used In) Operating Activities | 1,218 |  |  | 1,140 |  |
| CASH FLOWS FROM INVESTING ACTIVITIES |  |  |  |  |
| Additions to Property, Plant and Equipment | (795 | ) |  | (1,053 | ) |
| Purchase of Emissions Allowances and RECs | (21 | ) |  | (17 | ) |
| Proceeds from Sales of Trust Investments | 497 |  |  | 397 |  |
| Purchases of Trust Investments | (507 | ) |  | (407 | ) |
| Other | 10 |  |  | 7 |  |
| Net Cash Provided By (Used In) Investing Activities | (816 | ) |  | (1,073 | ) |
| CASH FLOWS FROM FINANCING ACTIVITIES |  |  |  |
| Net Change in Commercial Paper and Loans | 135 |  |  | 52 |  |
| Redemption of Long-Term Debt | (350 | ) |  | — |  |
| Cash Dividends Paid on Common Stock | (238 | ) |  | (227 | ) |
| Other | (52 | ) |  | (73 | ) |
| Net Cash Provided By (Used In) Financing Activities | (505 | ) |  | (248 | ) |
| Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash | (103 | ) |  | (181 | ) |
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 199 |  |  | 315 |  |
| Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 96 |  |  | $ | 134 |  |
| Supplemental Disclosure of Cash Flow Information: |  |  |  |
| Income Taxes Paid (Received) | $ | (76 | ) |  | $ | (4 | ) |
| Interest Paid, Net of Amounts Capitalized | $ | 91 |  |  | $ | 73 |  |
| Accrued Property, Plant and Equipment Expenditures | $ | 456 |  |  | $ | 544 |  |

See Notes to Condensed Consolidated Financial Statements.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Millions
(Unaudited)

|  |  | Common Stock |  | Treasury Stock |  | Retained Earnings |  | Accumulated Other Comprehensive Income (Loss) |  |
|  |  | Shs. |  | Amount |  | Shs. |  | Amount |  | Total |
| Balance as of January 1, 2019 |  | 534 |  |  | $ | 4,980 |  |  | (30 | ) |  | $ | (808 | ) |  | $ | 10,582 |  |  | $ | (377 | ) |  | $ | 14,377 |  |
| Net Income |  | — |  |  | — |  |  | — |  |  | — |  |  | 700 |  |  | — |  |  | 700 |  |
| Cumulative Effect Adjustment to Reclassify Stranded Tax Effects Resulting from the Change in the Federal Corporate Income Tax Rate |  | — |  |  | — |  |  | — |  |  | — |  |  | 81 |  |  | (81 | ) |  | — |  |
| Other Comprehensive Income (Loss), net of tax (expense) benefit of $(16) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 17 |  |  | 17 |  |
| Comprehensive Income |  |  |  |  |  |  |  |  |  |  |  |  |  | 717 |  |
| Cash Dividends at $0.47 per share on Common Stock |  | — |  |  | — |  |  | — |  |  | — |  |  | (238 | ) |  | — |  |  | (238 | ) |
| Other |  | — |  |  | (11 | ) |  | — |  |  | (31 | ) |  | — |  |  | — |  |  | (42 | ) |
| Balance as of March 31, 2019 |  | 534 |  |  | $ | 4,969 |  |  | (30 | ) |  | $ | (839 | ) |  | $ | 11,125 |  |  | $ | (441 | ) |  | $ | 14,814 |  |

|  |  | Common Stock |  | Treasury Stock |  | Retained Earnings |  | Accumulated Other Comprehensive Income (Loss) |  |
|  |  | Shs. |  | Amount |  | Shs. |  | Amount |  | Total |
| Balance as of January 1, 2018 |  | 534 |  |  | $ | 4,961 |  |  | (29 | ) |  | $ | (763 | ) |  | $ | 9,878 |  |  | $ | (229 | ) |  | $ | 13,847 |  |
| Net Income |  | — |  |  | — |  |  | — |  |  | — |  |  | 558 |  |  | — |  |  | 558 |  |
| Cumulative Effect Adjustment to Reclassify Unrealized Net Gains on Equity Investments |  | — |  |  | — |  |  | — |  |  | — |  |  | 176 |  |  | (176 | ) |  | — |  |
| Other Comprehensive Income (Loss), net of tax (expense) benefit of $6 |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (6 | ) |  | (6 | ) |
| Comprehensive Income |  |  |  |  |  |  |  |  |  |  |  |  |  | 552 |  |
| Cash Dividends at $0.45 per share on Common Stock |  | — |  |  | — |  |  | — |  |  | — |  |  | (227 | ) |  | — |  |  | (227 | ) |
| Other |  | — |  |  | (15 | ) |  | (1 | ) |  | (53 | ) |  | — |  |  | — |  |  | (68 | ) |
| Balance as of March 31, 2018 |  | 534 |  |  | $ | 4,946 |  |  | (30 | ) |  | $ | (816 | ) |  | $ | 10,385 |  |  | $ | (411 | ) |  | $ | 14,104 |  |

See Notes to Condensed Consolidated Financial Statements.
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PUBLIC SERVICE ELECTRIC AND GAS COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| OPERATING REVENUES | $ | 2,032 |  |  | $ | 1,845 |  |
| OPERATING EXPENSES |  |  |  |
| Energy Costs | 947 |  |  | 782 |  |
| Operation and Maintenance | 408 |  |  | 391 |  |
| Depreciation and Amortization | 212 |  |  | 190 |  |
| Total Operating Expenses | 1,567 |  |  | 1,363 |  |
| OPERATING INCOME | 465 |  |  | 482 |  |
| Net Gains (Losses) on Trust Investments | 1 |  |  | — |  |
| Other Income (Deductions) | 19 |  |  | 20 |  |
| Non-Operating Pension and OPEB Credits (Costs) | 30 |  |  | 15 |  |
| Interest Expense | (87 | ) |  | (81 | ) |
| INCOME BEFORE INCOME TAXES | 428 |  |  | 436 |  |
| Income Tax Benefit (Expense) | (25 | ) |  | (117 | ) |
| NET INCOME | $ | 403 |  |  | $ | 319 |  |

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.
7

Table of Contents
PUBLIC SERVICE ELECTRIC AND GAS COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| NET INCOME | $ | 403 |  |  | $ | 319 |  |
| Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit of $0 for 2019 and 2018 | 1 |  |  | (1 | ) |
| COMPREHENSIVE INCOME | $ | 404 |  |  | $ | 318 |  |

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.
8

Table of Contents
PUBLIC SERVICE ELECTRIC AND GAS COMPANY
CONDENSED CONSOLIDATED BALANCE SHEETS
Millions
(Unaudited)

|  | March 31, 2019 |  | December 31, 2018 |
| ASSETS |
| CURRENT ASSETS |  |  |  |
| Cash and Cash Equivalents | $ | 15 |  |  | $ | 39 |  |
| Accounts Receivable, net of allowances of $72 in 2019 and $63 in 2018 | 1,047 |  |  | 879 |  |
| Tax Receivable | — |  |  | 20 |  |
| Accounts Receivable—Affiliated Companies | — |  |  | 123 |  |
| Unbilled Revenues | 188 |  |  | 240 |  |
| Materials and Supplies, net | 201 |  |  | 196 |  |
| Prepayments | 23 |  |  | 10 |  |
| Regulatory Assets | 294 |  |  | 389 |  |
| Other | 19 |  |  | 11 |  |
| Total Current Assets | 1,787 |  |  | 1,907 |  |
| PROPERTY, PLANT AND EQUIPMENT | 32,114 |  |  | 31,633 |  |
| Less: Accumulated Depreciation and Amortization | (6,360 | ) |  | (6,277 | ) |
| Net Property, Plant and Equipment | 25,754 |  |  | 25,356 |  |
| NONCURRENT ASSETS |  |  |  |
| Regulatory Assets | 3,423 |  |  | 3,399 |  |
| Operating Lease Right-of-Use Assets | 89 |  |  | — |  |
| Long-Term Investments | 275 |  |  | 270 |  |
| Rabbi Trust Fund | 46 |  |  | 45 |  |
| Other | 126 |  |  | 132 |  |
| Total Noncurrent Assets | 3,959 |  |  | 3,846 |  |
| TOTAL ASSETS | $ | 31,500 |  |  | $ | 31,109 |  |

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.
9

Table of Contents
PUBLIC SERVICE ELECTRIC AND GAS COMPANY
CONDENSED CONSOLIDATED BALANCE SHEETS
Millions
(Unaudited)

|  | March 31, 2019 |  | December 31, 2018 |
| LIABILITIES AND CAPITALIZATION |
| CURRENT LIABILITIES |  |  |  |
| Long-Term Debt Due Within One Year | $ | 500 |  |  | $ | 500 |  |
| Commercial Paper and Loans | 364 |  |  | 272 |  |
| Accounts Payable | 528 |  |  | 713 |  |
| Accounts Payable—Affiliated Companies | 274 |  |  | 321 |  |
| Accrued Interest | 96 |  |  | 84 |  |
| Clean Energy Program | 85 |  |  | 143 |  |
| Obligation to Return Cash Collateral | 129 |  |  | 136 |  |
| Regulatory Liabilities | 320 |  |  | 311 |  |
| Other | 402 |  |  | 345 |  |
| Total Current Liabilities | 2,698 |  |  | 2,825 |  |
| NONCURRENT LIABILITIES |  |  |  |
| Deferred Income Taxes and ITC | 3,913 |  |  | 3,830 |  |
| Regulatory Liabilities | 3,148 |  |  | 3,221 |  |
| Operating Leases | 79 |  |  | — |  |
| Asset Retirement Obligations | 302 |  |  | 302 |  |
| OPEB Costs | 479 |  |  | 486 |  |
| Accrued Pension Costs | 391 |  |  | 400 |  |
| Environmental Costs | 304 |  |  | 268 |  |
| Long-Term Accrued Taxes | 69 |  |  | 69 |  |
| Other | 127 |  |  | 124 |  |
| Total Noncurrent Liabilities | 8,812 |  |  | 8,700 |  |
| COMMITMENTS AND CONTINGENT LIABILITIES (See Note 11) |  |  |  |  |  |
| CAPITALIZATION |  |  |  |
| LONG-TERM DEBT | 8,686 |  |  | 8,684 |  |
| STOCKHOLDER’S EQUITY |  |  |  |
| Common Stock; 150 shares authorized; issued and outstanding, 2019 and 2018—132 shares | 892 |  |  | 892 |  |
| Contributed Capital | 1,095 |  |  | 1,095 |  |
| Basis Adjustment | 986 |  |  | 986 |  |
| Retained Earnings | 8,331 |  |  | 7,928 |  |
| Accumulated Other Comprehensive Income (Loss) | — |  |  | (1 | ) |
| Total Stockholder’s Equity | 11,304 |  |  | 10,900 |  |
| Total Capitalization | 19,990 |  |  | 19,584 |  |
| TOTAL LIABILITIES AND CAPITALIZATION | $ | 31,500 |  |  | $ | 31,109 |  |

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.
10

Table of Contents
PUBLIC SERVICE ELECTRIC AND GAS COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |
| Net Income | $ | 403 |  |  | $ | 319 |  |
| Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: |  |  |  |
| Depreciation and Amortization | 212 |  |  | 190 |  |
| Provision for Deferred Income Taxes and ITC | (12 | ) |  | 40 |  |
| Non-Cash Employee Benefit Plan (Credits) Costs | (9 | ) |  | 9 |  |
| Cost of Removal | (30 | ) |  | (38 | ) |
| Net Change in Regulatory Assets and Liabilities | 69 |  |  | (6 | ) |
| Net Change in Certain Current Assets and Liabilities: |  |  |  |
| Accounts Receivable and Unbilled Revenues | (119 | ) |  | 24 |  |
| Materials and Supplies | (5 | ) |  | (2 | ) |
| Prepayments | 3 |  |  | 22 |  |
| Accounts Payable | (108 | ) |  | (12 | ) |
| Accounts Receivable/Payable—Affiliated Companies, net | 87 |  |  | 40 |  |
| Other Current Assets and Liabilities | 35 |  |  | 39 |  |
| Employee Benefit Plan Funding and Related Payments | (10 | ) |  | (33 | ) |
| Other | 4 |  |  | (15 | ) |
| Net Cash Provided By (Used In) Operating Activities | 520 |  |  | 577 |  |
| CASH FLOWS FROM INVESTING ACTIVITIES |  |  |  |
| Additions to Property, Plant and Equipment | (625 | ) |  | (750 | ) |
| Proceeds from Sales of Trust Investments | 10 |  |  | 5 |  |
| Purchases of Trust Investments | (9 | ) |  | (5 | ) |
| Solar Loan Investments | (5 | ) |  | (9 | ) |
| Other | 2 |  |  | 2 |  |
| Net Cash Provided By (Used In) Investing Activities | (627 | ) |  | (757 | ) |
| CASH FLOWS FROM FINANCING ACTIVITIES |  |  |  |
| Net Change in Commercial Paper and Loans | 92 |  |  | — |  |
| Net Cash Provided By (Used In) Financing Activities | 92 |  |  | — |  |
| Net Increase (Decrease) In Cash, Cash Equivalents and Restricted Cash | (15 | ) |  | (180 | ) |
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 61 |  |  | 244 |  |
| Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 46 |  |  | $ | 64 |  |
| Supplemental Disclosure of Cash Flow Information: |  |  |  |
| Income Taxes Paid (Received) | $ | (94 | ) |  | $ | — |  |
| Interest Paid, Net of Amounts Capitalized | $ | 73 |  |  | $ | 65 |  |
| Accrued Property, Plant and Equipment Expenditures | $ | 273 |  |  | $ | 326 |  |

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.
11

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 Other Comprehensive Income (Loss) |
|  |  |  |  |  | Total |
| Balance as of January 1, 2019 |  | $ | 892 |  |  | $ | 1,095 |  |  | $ | 986 |  |  | $ | 7,928 |  |  | $ | (1 | ) |  | $ | 10,900 |  |
| Net Income |  | — |  |  | — |  |  | — |  |  | 403 |  |  | — |  |  | 403 |  |
| Other Comprehensive Income (Loss), net of tax (expense) benefit of $0 |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | 1 |  |
| Comprehensive Income |  |  |  |  |  |  |  |  |  |  |  | 404 |  |
| Balance as of March 31, 2019 |  | $ | 892 |  |  | $ | 1,095 |  |  | $ | 986 |  |  | $ | 8,331 |  |  | $ | — |  |  | $ | 11,304 |  |

|  |  | Common Stock |  | Contributed Capital |  | Basis Adjustment |  | Retained Earnings |  | Accumulated Other Comprehensive Income (Loss) |
|  |  |  |  |  | Total |
| Balance as of January 1, 2018 |  | $ | 892 |  |  | $ | 1,095 |  |  | $ | 986 |  |  | $ | 6,861 |  |  | $ | — |  |  | $ | 9,834 |  |
| Net Income |  | — |  |  | — |  |  | — |  |  | 319 |  |  | — |  |  | 319 |  |
| Other Comprehensive Income (Loss), net of tax (expense) benefit of $0 |  | — |  |  | — |  |  | — |  |  | — |  |  | (1 | ) |  | (1 | ) |
| Comprehensive Income |  |  |  |  |  |  |  |  |  |  |  | 318 |  |
| Balance as of March 31, 2018 |  | $ | 892 |  |  | $ | 1,095 |  |  | $ | 986 |  |  | $ | 7,180 |  |  | $ | (1 | ) |  | $ | 10,152 |  |

See disclosures regarding Public Service Electric and Gas Company included in the Notes to Condensed Consolidated Financial Statements.
12

Table of Contents
PSEG POWER LLC
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| OPERATING REVENUES | $ | 1,416 |  |  | $ | 1,403 |  |
| OPERATING EXPENSES |  |  |  |
| Energy Costs | 786 |  |  | 746 |  |
| Operation and Maintenance | 235 |  |  | 246 |  |
| Depreciation and Amortization | 94 |  |  | 82 |  |
| Total Operating Expenses | 1,115 |  |  | 1,074 |  |
| OPERATING INCOME | 301 |  |  | 329 |  |
| Income from Equity Method Investments | 2 |  |  | 2 |  |
| Net Gains (Losses) on Trust Investments | 126 |  |  | (22 | ) |
| Other Income (Deductions) | 13 |  |  | 11 |  |
| Non-Operating Pension and OPEB Credits (Costs) | 3 |  |  | 4 |  |
| Interest Expense | (25 | ) |  | (7 | ) |
| INCOME BEFORE INCOME TAXES | 420 |  |  | 317 |  |
| Income Tax Benefit (Expense) | (124 | ) |  | (83 | ) |
| NET INCOME | $ | 296 |  |  | $ | 234 |  |

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.
13

Table of Contents
PSEG POWER LLC
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| NET INCOME | $ | 296 |  |  | $ | 234 |  |
| Other Comprehensive Income (Loss), net of tax |  |  |  |
| Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit of $(11) and $8 for 2019 and 2018, respectively | 16 |  |  | (11 | ) |
| Pension/OPEB adjustment, net of tax (expense) benefit of $(4) and $(3) for 2019 and 2018, respectively | — |  |  | 6 |  |
| Other Comprehensive Income (Loss), net of tax | 16 |  |  | (5 | ) |
| COMPREHENSIVE INCOME | $ | 312 |  |  | $ | 229 |  |

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.
14

Table of Contents
PSEG POWER LLC
CONDENSED CONSOLIDATED BALANCE SHEETS
Millions
(Unaudited)

|  | March 31, 2019 |  | December 31, 2018 |
| ASSETS |
| CURRENT ASSETS |  |  |  |
| Cash and Cash Equivalents | $ | 28 |  |  | $ | 22 |  |
| Accounts Receivable | 355 |  |  | 477 |  |
| Accounts Receivable—Affiliated Companies | 284 |  |  | 274 |  |
| Short-Term Loan to Affiliate | 87 |  |  | — |  |
| Fuel | 134 |  |  | 331 |  |
| Materials and Supplies, net | 381 |  |  | 373 |  |
| Derivative Contracts | 19 |  |  | 11 |  |
| Prepayments | 17 |  |  | 14 |  |
| Other | 7 |  |  | 5 |  |
| Total Current Assets | 1,312 |  |  | 1,507 |  |
| PROPERTY, PLANT AND EQUIPMENT | 12,396 |  |  | 12,224 |  |
| Less: Accumulated Depreciation and Amortization | (3,520 | ) |  | (3,382 | ) |
| Net Property, Plant and Equipment | 8,876 |  |  | 8,842 |  |
| NONCURRENT ASSETS |  |  |  |
| Operating Lease Right-of-Use Assets | 43 |  |  | — |  |
| Long-Term Investments | 86 |  |  | 86 |  |
| NDT Fund | 2,049 |  |  | 1,878 |  |
| Rabbi Trust Fund | 59 |  |  | 56 |  |
| Goodwill | 16 |  |  | 16 |  |
| Other Intangibles | 156 |  |  | 143 |  |
| Derivative Contracts | 4 |  |  | 1 |  |
| Other | 70 |  |  | 65 |  |
| Total Noncurrent Assets | 2,483 |  |  | 2,245 |  |
| TOTAL ASSETS | $ | 12,671 |  |  | $ | 12,594 |  |

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.
15

Table of Contents
PSEG POWER LLC
CONDENSED CONSOLIDATED BALANCE SHEETS
Millions
(Unaudited)

|  | March 31, 2019 |  | December 31, 2018 |
| LIABILITIES AND MEMBER’S EQUITY |
| CURRENT LIABILITIES |  |  |  |
| Long-Term Debt Due Within One Year | $ | — |  |  | $ | 44 |  |
| Accounts Payable | 472 |  |  | 498 |  |
| Accounts Payable—Affiliated Companies | 21 |  |  | 16 |  |
| Short-Term Loan from Affiliate | — |  |  | 193 |  |
| Derivative Contracts | 13 |  |  | 11 |  |
| Accrued Interest | 49 |  |  | 21 |  |
| Other | 83 |  |  | 59 |  |
| Total Current Liabilities | 638 |  |  | 842 |  |
| NONCURRENT LIABILITIES |  |  |  |
| Deferred Income Taxes and ITC | 1,755 |  |  | 1,619 |  |
| Operating Leases | 39 |  |  | — |  |
| Asset Retirement Obligations | 762 |  |  | 758 |  |
| OPEB Costs | 176 |  |  | 176 |  |
| Accrued Pension Costs | 243 |  |  | 246 |  |
| Derivative Contracts | 1 |  |  | 4 |  |
| Long-Term Accrued Taxes | 82 |  |  | 76 |  |
| Other | 117 |  |  | 122 |  |
| Total Noncurrent Liabilities | 3,175 |  |  | 3,001 |  |
| COMMITMENTS AND CONTINGENT LIABILITIES (See Note 11) |  |  |  |  |  |
| LONG-TERM DEBT | 2,836 |  |  | 2,791 |  |
| MEMBER’S EQUITY |  |  |  |
| Contributed Capital | 2,214 |  |  | 2,214 |  |
| Basis Adjustment | (986 | ) |  | (986 | ) |
| Retained Earnings | 5,166 |  |  | 5,051 |  |
| Accumulated Other Comprehensive Loss | (372 | ) |  | (319 | ) |
| Total Member’s Equity | 6,022 |  |  | 5,960 |  |
| TOTAL LIABILITIES AND MEMBER’S EQUITY | $ | 12,671 |  |  | $ | 12,594 |  |

See disclosures regarding PSEG Power LLC included in the Notes to Condensed Consolidated Financial Statements.
16

Table of Contents
PSEG POWER LLC
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Millions
(Unaudited)

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |
| Net Income | $ | 296 |  |  | $ | 234 |  |
| Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from Operating Activities: |  |  |  |
| Depreciation and Amortization | 94 |  |  | 82 |  |
| Amortization of Nuclear Fuel | 47 |  |  | 50 |  |
| Emission Allowances and REC Compliance Accrual | 24 |  |  | 24 |  |
| Provision for Deferred Income Taxes and ITC | 121 |  |  | 33 |  |
| Interest Accretion on Asset Retirement Obligation | 10 |  |  | 10 |  |
| Net Realized and Unrealized (Gains) Losses on Energy Contracts and Other Derivatives | (109 | ) |  | (119 | ) |
| Non-Cash Employee Benefit Plan (Credits) Costs | 4 |  |  | 6 |  |
| Net (Gains) Losses and (Income) Expense from NDT Fund | (137 | ) |  | 12 |  |
| Net Change in Certain Current Assets and Liabilities: |  |  |  |
| Fuel, Materials and Supplies | 189 |  |  | 133 |  |
| Margin Deposit | 190 |  |  | 25 |  |
| Accounts Receivable | 34 |  |  | 93 |  |
| Accounts Payable | (57 | ) |  | (89 | ) |
| Accounts Receivable/Payable—Affiliated Companies, net | (22 | ) |  | 25 |  |
| Other Current Assets and Liabilities | 37 |  |  | 30 |  |
| Employee Benefit Plan Funding and Related Payments | (3 | ) |  | (2 | ) |
| Other | 8 |  |  | (5 | ) |
| Net Cash Provided By (Used In) Operating Activities | 726 |  |  | 542 |  |
| CASH FLOWS FROM INVESTING ACTIVITIES |  |  |  |
| Additions to Property, Plant and Equipment | (167 | ) |  | (299 | ) |
| Purchase of Emissions Allowances and RECs | (21 | ) |  | (17 | ) |
| Proceeds from Sales of Trust Investments | 463 |  |  | 377 |  |
| Purchases of Trust Investments | (475 | ) |  | (389 | ) |
| Short-Term Loan—Affiliated Company | (87 | ) |  | — |  |
| Other | 11 |  |  | 11 |  |
| Net Cash Provided By (Used In) Investing Activities | (276 | ) |  | (317 | ) |
| CASH FLOWS FROM FINANCING ACTIVITIES |  |  |  |
| Cash Dividend Paid | (250 | ) |  | — |  |
| Short-Term Loan—Affiliated Company | (193 | ) |  | (246 | ) |
| Other | (1 | ) |  | — |  |
| Net Cash Provided By (Used In) Financing Activities | (444 | ) |  | (246 | ) |
| Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash | 6 |  |  | (21 | ) |
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 22 |  |  | 32 |  |
| Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 28 |  |  | $ | 11 |  |
| Supplemental Disclosure of Cash Flow Information: |  |  |  |
| Income Taxes Paid (Received) | $ | 11 |  |  | $ | 2 |  |
| Interest Paid, Net of Amounts Capitalized | $ | 6 |  |  | $ | 2 |  |
| Accrued Property, Plant and Equipment Expenditures | $ | 183 |  |  | $ | 218 |  |

See disclosures regarding PSEG Power LLC included in the Notes to the Condensed Consolidated Financial Statements.
17

Table of Contents
PSEG POWER LLC
CONDENSED CONSOLIDATED STATEMENTS OF MEMBER’S EQUITY
Millions
(Unaudited)

|  |  | Contributed Capital |  | Basis Adjustment |  | Retained Earnings |  | Accumulated Other Comprehensive Income (Loss) |  |
|  |  |  |  | Total |
| Balance as of January 1, 2019 |  | $ | 2,214 |  |  | $ | (986 | ) |  | $ | 5,051 |  |  | $ | (319 | ) |  | $ | 5,960 |  |
| Net Income |  | — |  |  | — |  |  | 296 |  |  | — |  |  | 296 |  |
| Cumulative Effect Adjustment to Reclassify Stranded Tax Effects Resulting from the Change in the Federal Corporate Income Tax Rate |  | — |  |  | — |  |  | 69 |  |  | (69 | ) |  | — |  |
| Other Comprehensive Income (Loss), net of tax (expense) benefit of $(15) |  | — |  |  | — |  |  | — |  |  | 16 |  |  | 16 |  |
| Comprehensive Income |  |  |  |  |  |  |  |  |  | 312 |  |
| Cash Dividends Paid |  | — |  |  | — |  |  | (250 | ) |  | — |  |  | (250 | ) |
| Balance as of March 31, 2019 |  | $ | 2,214 |  |  | $ | (986 | ) |  | $ | 5,166 |  |  | $ | (372 | ) |  | $ | 6,022 |  |

|  |  | Contributed Capital |  | Basis Adjustment |  | Retained Earnings |  | Accumulated Other Comprehensive Income (Loss) |  |
|  |  |  |  | Total |
| Balance as of January 1, 2018 |  | $ | 2,214 |  |  | $ | (986 | ) |  | $ | 4,911 |  |  | $ | (172 | ) |  | $ | 5,967 |  |
| Net Income |  | — |  |  | — |  |  | 234 |  |  | — |  |  | 234 |  |
| Cumulative Effect Adjustment to Reclassify Unrealized Net Gains on Equity Investments |  | — |  |  | — |  |  | 175 |  |  | (175 | ) |  | — |  |
| Other Comprehensive Income (Loss), net of tax (expense) benefit of $5 |  | — |  |  | — |  |  | — |  |  | (5 | ) |  | (5 | ) |
| Comprehensive Income |  |  |  |  |  |  |  |  |  | 229 |  |
| Balance as of March 31, 2018 |  | $ | 2,214 |  |  | $ | (986 | ) |  | $ | 5,320 |  |  | $ | (352 | ) |  | $ | 6,196 |  |

See disclosures regarding PSEG Power LLC included in the Notes to the Condensed Consolidated Financial Statements.
18

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 (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. In addition, Power owns and operates solar generation in various states. 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 Operations Services Agreement (OSA); PSEG Energy Holdings L.L.C. (Energy Holdings), which primarily has investments in leveraged leases; and PSEG Services Corporation (Services), which provides certain management, administrative and general services to PSEG and its subsidiaries at cost.
Basis of Presentation
The 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 principles 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, 2018.
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, 2018.
Significant Accounting Policies
Cash, Cash Equivalents and Restricted Cash
Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. Restricted cash consists primarily of deposits received related to various construction projects at PSE&G.
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, 2018) and ending periods shown in the Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2019.
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|  | PSE&G |  | Power |  | Other (A) |  | Consolidated |
|  | Millions |
| As of December 31, 2018 |  |  |  |  |  |  |  |
| Cash and Cash Equivalents | $ | 39 |  |  | $ | 22 |  |  | $ | 116 |  |  | $ | 177 |  |
| Restricted Cash in Other Current Assets | 8 |  |  | — |  |  | — |  |  | 8 |  |
| Restricted Cash in Other Noncurrent Assets | 14 |  |  | — |  |  | — |  |  | 14 |  |
| Cash, Cash Equivalents and Restricted Cash | $ | 61 |  |  | $ | 22 |  |  | $ | 116 |  |  | $ | 199 |  |
| As of March 31, 2019 |  |  |  |  |  |  |  |
| Cash and Cash Equivalents | $ | 15 |  |  | $ | 28 |  |  | $ | 22 |  |  | $ | 65 |  |
| Restricted Cash in Other Current Assets | 15 |  |  | — |  |  | — |  |  | 15 |  |
| Restricted Cash in Other Noncurrent Assets | 16 |  |  | — |  |  | — |  |  | 16 |  |
| Cash, Cash Equivalents and Restricted Cash | $ | 46 |  |  | $ | 28 |  |  | $ | 22 |  |  | $ | 96 |  |

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

Note 2. Recent Accounting Standards
New Standards Issued and Adopted
Leases—Accounting Standards Update (ASU) 2016-02, updated by ASUs 2018-01, 2018-10, 2018-11, 2018-20 and 2019-01
This accounting standard, and related updates, replace existing lease accounting guidance and require lessees to recognize leases with a term greater than 12 months on the balance sheet using a right-of-use asset approach. At lease commencement, a lessee will recognize a lease asset and corresponding lease obligation. A lessee will classify its leases as either finance leases or operating leases and a lessor will classify its leases as operating leases, direct financing leases, or as sales-type leases. The standard requires additional disclosure of key information. Existing guidance related to leveraged leases does not change.
PSEG adopted the optional transition method on January 1, 2019. There was no cumulative effect adjustment required to be recorded to Retained Earnings at adoption. The optional transition method requires disclosure under Accounting Standards Codification (ASC) 840—Leases, the previously existing lease guidance for prior periods.
PSEG elected various practical expedients allowed by the standard, including the package of three practical expedients related to not reassessing existing or expired contracts and initial direct costs; and excluding evaluation of land easements that exist or expired before adoption that were not previously accounted for as leases.
The impact of adoption on PSEG’s Consolidated Balance Sheet was to record Operating Lease Right of Use Assets of $261 million and Operating Lease Liabilities of $282 million. As part of that impact, PSEG reclassified deferred rent incentives and deferred rent liabilities of approximately $21 million, which were previously classified as Other Noncurrent Liabilities, to Operating Lease Right-of-Use Assets in accordance with this standard. PSE&G’s assets and liabilities each increased by $91 million and Power’s assets and liabilities each increased by $46 million. PSEG’s adoption of this standard did not have a material impact on the Consolidated Statements of Operations or Consolidated Statements of Cash Flows of PSEG, PSE&G and Power. See Note 7. Leases for additional information.
Derivatives and Hedging: Targeted Improvements to Accounting for Hedging Activities—ASU 2017-12, updated by ASU 2018-16
This accounting standard’s amendments more closely align hedge accounting with companies’ risk management activities in the financial statements and ease the operational burden of applying hedge accounting.
PSEG adopted this standard on January 1, 2019. The standard requires using a modified retrospective method upon adoption. PSEG analyzed the impact of this standard on its consolidated financial statements and has determined that the standard could enable PSEG to enter into certain transactions that can be deemed hedges that previously would not have qualified. Adoption of this standard did not have a material impact on PSEG’s financial statements.
Premium Amortization on Purchased Callable Debt Securities—ASU 2017-08
This accounting standard was issued to shorten the amortization period for certain callable debt securities held at a premium. Specifically, the standard requires the premium to be amortized to the earliest call date.
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PSEG adopted this standard on January 1, 2019 on a modified retrospective basis through a cumulative effect adjustment directly to Retained Earnings as of the beginning of 2019. Adoption of this standard did not have a material impact on PSEG’s financial statements.
Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income—ASU 2018-02
This accounting standard affects any entity that is required to apply the provisions of the ASC topic, “Income Statement-Reporting Comprehensive Income,” and has items of Other Comprehensive Income for which the related tax effects are presented in Other Comprehensive Income as required by GAAP. Specifically, this standard allows entities to record a reclassification from Accumulated Other Comprehensive Income to Retained Earnings for stranded tax effects resulting from the recent decrease in the federal corporate income tax rate.
PSEG adopted this standard on January 1, 2019. The impact of adoption on PSEG’s Consolidated Balance Sheet was to increase Retained Earnings and Accumulated Other Comprehensive Loss by approximately $81 million. Power’s Retained Earnings and Accumulated Other Comprehensive Loss increased by approximately $69 million. The impact on PSE&G’s Consolidated Balance Sheet was immaterial. PSEG’s adoption of this standard did not have a material impact on the Consolidated Statements of Operations or Consolidated Statements of Cash Flows of PSEG, PSE&G and Power.
New Standards Issued But Not Yet Adopted
Measurement of Credit Losses on Financial Instruments—ASU 2016-13, updated by ASU 2018-19
This accounting standard provides a new model for recognizing credit losses on financial assets carried at amortized cost. The new model requires entities to use an estimate of expected credit losses that will be recognized as an impairment allowance rather than a direct write-down of the amortized cost basis. The estimate of expected credit losses is to be based on past events, current conditions and supportable forecasts over a reasonable period. For purchased financial assets with credit deterioration, a similar model is to be used; however, the initial allowance will be added to the purchase price rather than reported as an allowance. Credit losses on available-for-sale securities should be measured in a manner similar to current GAAP; however, this standard requires those credit losses to be presented as an allowance, rather than a write-down. This new standard also requires additional disclosures of credit quality indicators for each class of financial asset disaggregated by year of origination.
The standard is effective for annual and interim periods beginning after December 15, 2019; however, entities may adopt early beginning in the annual or interim periods after December 15, 2018. PSEG is currently analyzing the impact of this standard on its financial statements.
Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement—ASU 2018-13
This accounting standard modifies the disclosure requirements for fair value measurements. Certain current disclosure requirements relating to Level 3 fair value measurements, and transfers between Level 1 and Level 2 fair value measurements will be eliminated. The standard will also add certain other disclosure requirements for Level 3 fair value measurements.
The standard is effective for annual and interim periods beginning after December 15, 2019. Certain amendments in the standard should be applied prospectively for only the most recent interim or annual period presented in the initial fiscal year of adoption. All other amendments of the standard should be applied retrospectively to all periods presented upon their effective date. Early adoption is permitted. PSEG is currently analyzing the impact of this standard on its financial statements.
Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract—ASU 2018-15
This accounting standard aligns the capitalization requirements for implementation costs incurred in a hosting arrangement that is a service contract with capitalization requirements for implementation costs incurred to develop or obtain internal-use software, including hosting arrangements that include an internal-use software license. The standard follows the guidance in ASC 350—Intangibles—Goodwill and Other to determine which implementation costs to capitalize as an asset related to the service contract and which costs to expense. The standard requires the amortization of capitalized costs to be presented in Operation and Maintenance (O&M) Expense. In addition, the standard also adds presentation requirements for these costs in the statements of cash flows and financial position.
The standard is effective for annual and interim periods beginning after December 15, 2019. Early adoption is permitted, including adoption in any interim period. This standard should be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption. PSEG is currently analyzing the impact of this standard on its financial statements.
Targeted Improvements to Related Party Guidance for Variable Interest Entities (VIE)-ASU 2018-17
This accounting standard improves the VIE guidance in the area of decision-making fees. Consistent with how indirect interests
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held through related parties under common control are considered for determining whether a reporting entity must consolidate a VIE, indirect interests held through related parties in common control arrangements should be considered on a proportional basis for determining whether fees paid to decision makers and service providers are variable interests.
This standard is effective for annual and interim periods beginning after December 15, 2019. The standard is required to be applied retrospectively with a cumulative effect adjustment to Retained Earnings at the beginning of the earliest period presented. Early adoption is permitted. PSEG is currently analyzing the impact of this standard on its financial statements.
Simplifying the Test for Goodwill Impairment—ASU 2017-04
This accounting standard requires an entity to perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. Additionally, an entity should consider income tax effects from any tax deductible goodwill on the carrying amount of the reporting unit when measuring the goodwill impairment loss, if applicable.
An entity should apply this standard on a prospective basis and will be required to disclose the nature of and reason for the change in accounting principle upon transition. The new standard is effective for impairment tests for periods beginning January 1, 2020. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. PSEG does not expect adoption of this standard to have a material impact on its financial statements.
Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans—ASU 2018-14
This accounting standard modifies the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans, including the elimination of certain current disclosure requirements. Certain other disclosure requirements related to interest crediting rates have been added and certain clarifications were made to other disclosure requirements.
The standard is effective for fiscal years ending after December 15, 2020 and early adoption is permitted. An entity should apply the amendments in this standard on a retrospective basis to all periods presented. PSEG is currently analyzing the impact of this standard on its financial statements.
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 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 services are delivered to the customer. The electric and gas commodity and delivery tariffs are recurring contracts in effect until cancellation by the customer. 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 FERC tariff. The performance obligation of transmission service is satisfied over time as it is provided to and consumed by the customer. Revenue is recognized upon delivery of the transmission service. PSE&G’s revenues from the transmission of electricity are recorded based on a FERC-approved annual formula rate mechanism. This 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 within 30 days of month of delivery.
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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 weather normalization, green energy program true-ups and transmission formula rate true-ups, are not a material source of PSE&G revenues.
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 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. 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. 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.
Power enters into capacity sales and capacity purchases through the ISOs. The transactions are reported on a net basis dependent on 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, 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.
Gas Contracts—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, 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
Power enters into bilateral contracts to sell solar power and solar RECs from its solar facilities. Contract terms range from 15 to 30 years. The performance obligations are generally solar power and RECs which are transferred to customers upon generation. Revenue is recognized upon generation of the solar power.
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
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. Power is also a party to solar contracts that qualify as leases and are accounted for in accordance with lease accounting guidance.
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.
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Disaggregation of Revenues

|  | PSE&G |  | Power |  | Other |  | Eliminations |  | Consolidated |
|  | Millions |
| Three Months Ended March 31, 2019 |  |  |  |  |  |  |  |  |  |
| Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |
| Electric Distribution | $ | 742 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 742 |  |
| Gas Distribution | 931 |  |  | — |  |  | — |  |  | (3 | ) |  | 928 |  |
| Transmission | 288 |  |  | — |  |  | — |  |  | — |  |  | 288 |  |
| Electricity and Related Product Sales |  |  |  |  |  |  |  |  |  |
| PJM |  |  |  |  |  |  |  |  |  |
| Third Party Sales | — |  |  | 515 |  |  | — |  |  | — |  |  | 515 |  |
| Sales to Affiliates | — |  |  | 126 |  |  | — |  |  | (126 | ) |  | — |  |
| New York ISO | — |  |  | 41 |  |  | — |  |  | — |  |  | 41 |  |
| ISO New England | — |  |  | 21 |  |  | — |  |  | — |  |  | 21 |  |
| Gas Sales |  |  |  |  |  |  |  |  |  |
| Third Party Sales | — |  |  | 47 |  |  | — |  |  | — |  |  | 47 |  |
| Sales to Affiliates | — |  |  | 479 |  |  | — |  |  | (479 | ) |  | — |  |
| Other Revenues from Contracts with Customers (A) | 64 |  |  | 10 |  |  | 131 |  |  | (1 | ) |  | 204 |  |
| Total Revenues from Contracts with Customers | 2,025 |  |  | 1,239 |  |  | 131 |  |  | (609 | ) |  | 2,786 |  |
| Revenues Unrelated to Contracts with Customers (B) | 7 |  |  | 177 |  |  | 10 |  |  | — |  |  | 194 |  |
| Total Operating Revenues | $ | 2,032 |  |  | $ | 1,416 |  |  | $ | 141 |  |  | $ | (609 | ) |  | $ | 2,980 |  |

|  | PSE&G |  | Power |  | Other |  | Eliminations |  | Consolidated |
|  | Millions |
| Three Months Ended March 31, 2018 |  |  |  |  |  |  |  |  |  |
| Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |
| Electric Distribution | $ | 690 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 690 |  |
| Gas Distribution | 759 |  |  | — |  |  | — |  |  | (3 | ) |  | 756 |  |
| Transmission | 312 |  |  | — |  |  | — |  |  | — |  |  | 312 |  |
| Electricity and Related Product Sales |  |  |  |  |  |  |  |  |  |
| PJM |  |  |  |  |  |  |  |  |  |
| Third Party Sales | — |  |  | 498 |  |  | — |  |  | — |  |  | 498 |  |
| Sales to Affiliates | — |  |  | 176 |  |  | — |  |  | (176 | ) |  | — |  |
| New York ISO | — |  |  | 59 |  |  | — |  |  | — |  |  | 59 |  |
| ISO New England | — |  |  | 47 |  |  | — |  |  | — |  |  | 47 |  |
| Gas Sales |  |  |  |  |  |  |  |  |  |
| Third Party Sales | — |  |  | 64 |  |  | — |  |  | — |  |  | 64 |  |
| Sales to Affiliates | — |  |  | 397 |  |  | — |  |  | (397 | ) |  | — |  |
| Other Revenues from Contracts with Customers (A) | 72 |  |  | 10 |  |  | 137 |  |  | (1 | ) |  | 218 |  |
| Total Revenues from Contracts with Customers | 1,833 |  |  | 1,251 |  |  | 137 |  |  | (577 | ) |  | 2,644 |  |
| Revenues Unrelated to Contracts with Customers (B) | 12 |  |  | 152 |  |  | 10 |  |  | — |  |  | 174 |  |
| Total Operating Revenues | $ | 1,845 |  |  | $ | 1,403 |  |  | $ | 147 |  |  | $ | (577 | ) |  | $ | 2,818 |  |

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

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

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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 March 31, 2019 and December 31, 2018. Substantially all of PSE&G’s accounts receivable result from contracts with customers. Allowances represented approximately six percent and seven percent of accounts receivable as of March 31, 2019 and December 31, 2018, respectively.
Power
Power generally collects consideration upon satisfaction of performance obligations, and therefore, Power had no material contract balances as of March 31, 2019 and December 31, 2018.
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. In the wholesale energy markets in which Power operates, payment for services rendered and products transferred are typically due within 30 days of month of delivery. As such, there is little credit risk associated with these receivables and Power typically records no allowances.
Other
PSEG LI did not have any material contract balances as of March 31, 2019 and December 31, 2018.
Remaining Performance Obligations under Fixed Consideration Contracts
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:
Power
As stated above, capacity transactions with ISOs are reported on a net basis dependent on Power’s monthly net sale or purchase position through the individual ISOs.
Capacity Payments from the PJM Reliability Pricing Model (RPM) Annual Base Residual and Incremental Auctions—The Base Residual Auction is conducted annually three years in advance of the operating period. Power expects to realize the following average capacity prices for capacity obligations to be satisfied resulting from the base and incremental auctions which have been completed:

| Delivery Year |  | $ per MW-Day |  | MW Cleared |
| June 2018 to May 2019 |  | $205 |  | 9,200 |  |
| June 2019 to May 2020 |  | $115 |  | 9,000 |  |
| June 2020 to May 2021 |  | $170 |  | 8,100 |  |
| June 2021 to May 2022 |  | $178 |  | 7,700 |  |

Capacity Payments from the New England ISO Forward Capacity Market—The Forward Capacity Market (FCM) Auction is conducted annually three years in advance of the operating period. The table below includes 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, with escalations based on the Handy-Whitman Index and the planned retirement of Bridgeport Harbor Station 3 in 2021. Power expects to realize the following average capacity prices for capacity obligations to be satisfied resulting from the FCM auctions which have been completed:
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| Delivery Year |  | $ per MW-Day |  | MW Cleared |
| June 2018 to May 2019 |  | $314 |  | 820 |  |
| June 2019 to May 2020 |  | $231 |  | 1,330 |  |
| June 2020 to May 2021 |  | $195 |  | 1,330 |  |
| June 2021 to May 2022 |  | $192 |  | 950 |  |
| June 2022 to May 2023 |  | $179 |  | 950 |  |
| June 2023 to May 2024 |  | $231 |  | 480 |  |
| June 2024 to May 2025 |  | $231 |  | 480 |  |
| June 2025 to May 2026 |  | $231 |  | 480 |  |

Bilateral capacity contracts—Capacity obligations pursuant to contract terms through 2029 are anticipated to result in revenues totaling $177 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 2019 is $65 million and could increase each year based on the change in the Consumer Price Index (CPI). The incentive for 2019 can range from zero to approximately $10 million and could increase each year thereafter based on the change in the CPI.
Note 4. Early Plant Retirements
Nuclear
In May 2018, the governor of New Jersey signed legislation, referred to as the Zero Emission Certificate (ZEC) legislation, that recognizes that nuclear power is a critical component of New Jersey’s clean energy portfolio and an important element of a diverse energy generation portfolio that currently meets approximately 40 percent of New Jersey’s electric power needs. The ZEC legislation created a program administered by the BPU. The BPU established processes to provide for the purchase of ZECs from selected nuclear plants and recovery of those ZEC payments through a non-bypassable distribution charge (ZEC charge) in the amount of $0.004 per kilowatt-hour (which is equivalent to approximately $10 per megawatt hour (MWh)) in payments to selected nuclear plants.
In April 2019, Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs. As a result, the final “must-offer” exception requests and deactivation notices previously submitted to the PJM Independent Market Monitor and the PJM Office of Interconnection for the Salem and Hope Creek plants have been withdrawn. These nuclear plants are expected to receive ZEC revenue for approximately three years, through May 2022, and will be obligated to maintain operations, subject to exceptions specified in the ZEC legislation. Power anticipates it will recognize revenue monthly as the nuclear plants generate electricity and satisfy their performance obligations. The ZEC legislation requires nuclear plants to reapply for any subsequent three year periods. The ZEC payment may be adjusted by the BPU (a) at any time to offset environmental or fuel diversity payments that a selected nuclear plant may receive from another source or (b) at certain times specified in the ZEC legislation if the BPU determines that the purposes of the ZEC legislation can be achieved through a reduced charge that will nonetheless be sufficient to achieve the state’s air quality and other environmental objectives by preventing the retirement of nuclear plants. The financial condition of the plants may nonetheless be materially adversely impacted by potential changes to the capacity market construct being considered by FERC (absent sufficient capacity revenues provided under a program approved by the BPU in accordance with a FERC authorized capacity mechanism), and, 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. Absent a material financial change, these adverse impacts could still result in Power taking all necessary steps to retire all of these plants following the end of the initial three year term of the ZECs program. Retirement of these plants would result in a material adverse impact on PSEG’s and Power’s financial results.
Fossil
PSEG and Power monitor their coal assets, including the Keystone and Conemaugh generating stations, to assess their economic viability through the end of their designated useful lives and their continued classification as held for use. The precise timing of a change in useful lives may be dependent upon events out of PSEG’s and Power’s control and may impact their ability to operate or maintain certain assets in the future. These generating stations may be impacted by factors such as environmental legislation, co-owner capital requirements and continued depressed wholesale power prices or capacity factors,
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among other things. Any early retirement or change in the held for use classification of our remaining coal units may have a material adverse impact on PSEG’s and Power’s future financial results.
Note 5. Variable Interest Entity (VIE)
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 reimbursable 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 reimbursement 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 O&M Expense, respectively. Servco recorded $115 million and $120 million for the three months ended March 31, 2019 and 2018, respectively, 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.
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, 2018.
In addition to items previously reported in the Annual Report on Form 10-K, significant regulatory orders received and currently pending rate filings with the BPU by PSE&G are as follows:
BGSS—In March 2019, the BPU approved the final BGSS rates which were effective October 1, 2018.
Weather Normalization Clause (WNC)—In March 2019, the BPU gave final approval to PSE&G’s 2017-2018 WNC petition allowing a net recovery of $14 million to be collected over the 2018-2019 Winter Period with the new rate effective November 1, 2018. The $14 million net recovery is the result of $9 million of excess revenues from the colder than normal 2017-2018 Winter Period offset by $23 million of remaining prior Winter Period undercollection.
Gas System Modernization Program I (GSMP I)—In April 2019, PSE&G filed its final GSMP I cost recovery petition seeking BPU approval to recover in gas base rates an estimated annual revenue increase of $12 million effective October 1, 2019. This increase represents the return on and of GSMP I investments expected to be in service through June 30, 2019. This request will be updated in July 2019 for actual costs.
Note 7. Leases
PSEG and its subsidiaries, when acting as lessee or lessor, determine if an arrangement is a lease at inception. PSEG assesses contracts to determine if the arrangement conveys (i) the right to control the use of the identified property, (ii) the right to obtain substantially all of the economic benefits from the use of the property, and (iii) the right to direct the use of the property.
As of March 31, 2019, PSEG and subsidiaries were both a lessee and a lessor in Operating Leases. PSEG and subsidiaries were neither the lessee nor the lessor in any material non-operating leases.
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Lessee
The current portion of Operating Lease Liabilities is included in Other Current Liabilities. Operating Lease Right-of-Use Assets and noncurrent Operating Lease Liabilities are included as separate captions in Noncurrent Assets and Noncurrent Liabilities, respectively, on the Condensed Consolidated Balance Sheets of PSEG, PSE&G and Power. PSEG and its subsidiaries have elected an accounting policy to exclude the application of ASC 842 requirements to recognize Operating Lease Right-of-Use Assets and Operating Lease Liabilities for leases where the term is twelve months or less.
Operating Lease Right-of-Use Assets represent the right to use an underlying asset for the lease term and Operating Lease Liabilities represent the obligation to make lease payments arising from the lease. Operating Lease Right-of-Use Assets and Operating Lease Liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term.
PSEG and its subsidiaries recognize the lease payments in O&M Expense on a straight-line basis over the term of the leases and variable lease payments in the period in which the obligations for those payments are incurred.
As lessee, most of the Operating Leases of PSEG and its subsidiaries do not provide an implicit rate; therefore, incremental borrowing rates are used based on the information available at commencement date in determining the present value of lease payments. The implicit rate is used when readily determinable. PSE&G’s incremental borrowing rates are based on secured borrowing rates. PSEG’s and Power’s borrowing rates are generally unsecured rates. Having calculated simulated secured rates for each of PSEG and Power, it was determined that the difference between the unsecured borrowing rates and the simulated secured rates had an immaterial effect on their recorded Operating Lease Right-of-Use Assets and Operating Lease Liabilities.
Services, PSEG LI and other subsidiaries of PSEG that do not borrow funds or issue debt may enter into leases. Since these companies do not have credit ratings and related incremental borrowing rates, PSEG has determined that it is appropriate for these companies to use the incremental borrowing rate of PSEG, the parent company.
Lease terms may include options to extend or terminate the lease when it is reasonably certain that such options will be exercised.
PSEG and its subsidiaries have lease agreements with lease and non-lease components. For real estate, equipment and vehicle leases, the lease and non-lease components are accounted for as a single lease component.
PSE&G
PSE&G has Operating Leases for office space for customer service centers; rooftops and land for its Solar 4 All® facilities; equipment; vehicles; and land for certain electric substations. These leases have remaining lease terms through 2039, some of which include options to extend the leases for terms of one to five years. Some leases have fixed rent payments that have escalations based on certain indices, such as the CPI. Certain leases contain variable payments.
Power
Power has Operating Leases for buildings; land leases for its solar generating facilities; and equipment. These leases have remaining terms through 2052, some of which include options to extend the leases for one or more five-year terms and certain other leases which include options to extend the leases for 15 to 20 year terms. Some leases have fixed rent payments that have escalations based on certain indices, such as the CPI.
Other
Services has Operating Leases for real estate and office equipment. These leases have remaining terms through 2030. Services’ lease for its headquarters, which ends in 2030, includes options to extend for two five-year terms. Energy Holdings has land leases with remaining lease terms through 2027, some of which include options to extend the leases for up to eight five-year terms. Some leases have fixed rent payments that have escalations based on certain indices, such as the CPI. Certain leases contain variable payments.
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Operating Lease Costs
The following amounts relate to total Operating Lease costs, including both amounts recognized in the Condensed Consolidated Statements of Operations during the three months ended March 31, 2019 and any amounts capitalized as part of the cost of another asset, and the cash flows arising from lease transactions.

|  | PSE&G |  | Power |  | Other |  | Total |
|  | Millions |
| Three Months Ended March 31, 2019 |  |  |  |  |  |  |  |
| Operating Lease Costs |  |  |  |  |  |  |  |
| Long-term Lease Costs | $ | 4 |  |  | $ | 2 |  |  | $ | 4 |  |  | $ | 10 |  |
| Short-term Lease Costs | 5 |  |  | 2 |  |  | — |  |  | 7 |  |
| Variable Lease Costs | — |  |  | — |  |  | 3 |  |  | 3 |  |
| Total Operating Lease Costs | $ | 9 |  |  | $ | 4 |  |  | $ | 7 |  |  | $ | 20 |  |
| Cash Paid for Amounts Included in the Measurement of Operating Lease Liabilities | $ | 4 |  |  | $ | 2 |  |  | $ | 4 |  |  | $ | 10 |  |
| Weighted Average Remaining Lease Term in Years | 13 |  |  | 20 |  |  | 11 |  |  | 13 |  |
| Weighted Average Discount Rate | 3.7 | % |  | 5.0 | % |  | 4.2 | % |  | 4.2 | % |

Operating Lease commitments as of December 31, 2018 had the following maturities:

|  |  | PSE&G |  | Power |  | Other |  | Total |
|  |  | Millions |
| 2019 |  | $ | 15 |  |  | $ | 11 |  |  | $ | 15 |  |  | $ | 41 |  |
| 2020 |  | 11 |  |  | 13 |  |  | 16 |  |  | 40 |  |
| 2021 |  | 10 |  |  | 13 |  |  | 16 |  |  | 39 |  |
| 2022 |  | 8 |  |  | 14 |  |  | 16 |  |  | 38 |  |
| 2023 |  | 8 |  |  | 8 |  |  | 15 |  |  | 31 |  |
| Thereafter |  | 66 |  |  | 51 |  |  | 105 |  |  | 222 |  |
| Total Minimum Lease Payments |  | $ | 118 |  |  | $ | 110 |  |  | $ | 183 |  |  | $ | 411 |  |

Operating Lease Liabilities as of March 31, 2019 had the following maturities:

|  |  | PSE&G |  | Power |  | Other |  | Total |
|  |  | Millions |
| 2019 |  | $ | 11 |  |  | $ | 5 |  |  | $ | 12 |  |  | $ | 28 |  |
| 2020 |  | 11 |  |  | 4 |  |  | 16 |  |  | 31 |  |
| 2021 |  | 10 |  |  | 4 |  |  | 16 |  |  | 30 |  |
| 2022 |  | 8 |  |  | 5 |  |  | 16 |  |  | 29 |  |
| 2023 |  | 8 |  |  | 3 |  |  | 15 |  |  | 26 |  |
| 2024 |  | 7 |  |  | 3 |  |  | 14 |  |  | 24 |  |
| Thereafter |  | 60 |  |  | 46 |  |  | 90 |  |  | 196 |  |
| Total Minimum Lease Payments |  | $ | 115 |  |  | $ | 70 |  |  | $ | 179 |  |  | $ | 364 |  |

As of March 31, 2019, Power was a lessee in an operating lease that was executed but had not yet commenced and, therefore, no lease asset or liability was recognized. Fixed payments under this contract aggregating $35 million are due through 2023 and are not included in the above table.
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The following is a reconciliation of the undiscounted cash flows to the discounted Operating Lease Liabilities recognized on the Condensed Consolidated Balance Sheets:

|  |  | As of March 31, 2019 |
|  |  | PSE&G |  | Power |  | Other |  | Total |
|  |  | Millions |
| Undiscounted Cash Flows |  | $ | 115 |  |  | $ | 70 |  |  | $ | 179 |  |  | $ | 364 |  |
| Reconciling Amount due to Discount Rate |  | (25 | ) |  | (27 | ) |  | (37 | ) |  | (89 | ) |
| Total Discounted Operating Lease Liabilities |  | $ | 90 |  |  | $ | 43 |  |  | $ | 142 |  |  | $ | 275 |  |

As of March 31, 2019, the current portions of Operating Lease Liabilities included in Other Current Liabilities were $25 million, $11 million and $4 million for PSEG, PSE&G and Power, respectively.
Lessor
Property subject to Operating Leases, where PSEG or one of its subsidiaries is the lessor, is included in Property, Plant and Equipment and rental income from these leases is included in Operating Revenues.
PSEG and its subsidiaries, as lessors, have lease agreements with lease and non-lease components, which are primarily related to real estate assets and solar generating facilities. PSEG and subsidiaries account for the lease and non-lease components as a single lease component. Energy Holdings’ leveraged leases are accounted for in Operating Revenues and in Noncurrent Long-Term Investments. See Note 8. Financing Receivables.
Power
Certain of Power’s sales agreements related to its solar generating plants qualify as Operating Leases with remaining terms through 2043 with no extension terms. Lease income is based on solar energy generation; therefore, all rental income is variable under these leases. As of March 31, 2019, Power’s solar generating plants subject to these leases had a total carrying value of $331 million.
Other
Energy Holdings is the lessor in leveraged leases. Leveraged lease accounting guidance is grandfathered for existing leveraged leases. If modified after January 1, 2019, those leveraged leases will be accounted for as operating or financing leases. See Note 8. Financing Receivables.
Energy Holdings is the lessor in various Operating Leases for real estate with remaining terms through 2033. As of March 31, 2019, Energy Holdings’ property subject to these leases had a total carrying value of $24 million.
The following is the Operating Lease Income for Power and Energy Holdings for the three months ended March 31, 2019:

|  | Power |  | Energy Holdings |  | Total |
|  | Millions |
| Operating Lease Income |  |  |  |  |  |  |
| Fixed Lease Income | $ | — |  |  | $ | 5 |  |  | $ | 5 |  |
| Variable Lease Income | 4 |  |  | — |  |  | 4 |  |
| Total Operating Lease Income | $ | 4 |  |  | $ | 5 |  |  | $ | 9 |  |

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Energy Holdings’ Operating Leases had the following minimum future fixed lease receipts as of March 31, 2019:

|  |  | Millions |
| 2019 |  | $ | 19 |  |  |
| 2020 |  | 20 |  |  |
| 2021 |  | 18 |  |  |
| 2022 |  | 17 |  |  |
| 2023 |  | 17 |  |  |
| 2024 |  | 16 |  |  |
| Thereafter |  | 165 |  |  |
| Total Minimum Future Lease Receipts |  | $ | 272 |  |  |

Note 8. Financing Receivables
PSE&G
PSE&G sponsors a solar loan program 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 generally paid back with solar renewable energy certificates (SRECs) generated from the installed solar electric system. In the event of a loan default, the basis of the solar loan would be recovered through a regulatory recovery mechanism. None of the solar loans are impaired; however, in the event a loan becomes impaired, the basis of the loan would be recovered through a regulatory recovery mechanism. 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.”

| Outstanding Loans by Class of Customer |
|  |  | As of |  | As of |
| Consumer Loans |  | March 31, 2019 |  | December 31, 2018 |
|  |  | Millions |
| Commercial/Industrial |  | $ | 169 |  |  | $ | 164 |  |
| Residential |  | 9 |  |  | 9 |  |
| Total |  | $ | 178 |  |  | $ | 173 |  |
| Current Portion (included in Other Current Assets) |  | (22 | ) |  | (24 | ) |
| Noncurrent Portion (included in Long-Term Investments) |  | $ | 156 |  |  | $ | 149 |  |

Energy Holdings
Energy Holdings, through several of its indirect subsidiary companies, has investments in domestic energy and real estate 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.
In December 2018, REMA emerged from its in-court proceeding under Chapter 11 of the Bankruptcy Code. Upon emergence, PSEG received $31.5 million in cash in exchange for transferring the ownership interests in Keystone and Conemaugh to the debtholders of REMA and satisfaction of all other claims asserted against REMA, as well as certain amendments to the Shawville lease. The Shawville lease amendments, among other things, will allow REMA to express interest in a renewal on or after November 24, 2019. In addition, REMA has agreed to fund qualifying credit support up to $36 million. The remaining
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deferred tax liabilities related to these lease investments were reclassified to current tax liabilities. PSEG expects to pay approximately $120 million to taxing authorities in 2019 resulting from this restructuring activity.
The following table shows Energy Holdings’ gross and net lease investment as of March 31, 2019 and December 31, 2018.

|  | As of |  | As of |
|  | March 31, 2019 |  | December 31, 2018 |
|  | Millions |
| Lease Receivables (net of Non-Recourse Debt) | $ | 502 |  |  | $ | 504 |  |
| Estimated Residual Value of Leased Assets | 326 |  |  | 326 |  |
| Total Investment in Rental Receivables | 828 |  |  | 830 |  |
| Unearned and Deferred Income | (285 | ) |  | (290 | ) |
| Gross Investments in Leases | 543 |  |  | 540 |  |
| Deferred Tax Liabilities | (356 | ) |  | (354 | ) |
| Net Investments in Leases | $ | 187 |  |  | $ | 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 Non-Recourse Debt |
| Counterparties’ Credit Rating Standard & Poor’s (S&P) as of March 31, 2019 |  |  |
|  | As of March 31, 2019 |
|  |  | Millions |
| AA |  | $ | 13 |  |
| A- |  | 58 |  |
| BBB+ — BBB- |  | 258 |  |
| BB |  | 133 |  |
| NR |  | 40 |  |
| Total |  | $ | 502 |  |

The “BB” and the “NR” ratings in the preceding table represent lease receivables related to coal and gas-fired assets in Illinois and Pennsylvania, respectively. As of March 31, 2019, the gross investment in the leases of such assets, net of non-recourse debt, was $295 million ($7 million, net of deferred taxes). A more detailed description of such assets under lease is presented in the following table.

| Asset |  | Location |  | Gross Investment |  | % Owned |  | Total MW |  | Fuel Type |  | Counterparties’ S&P Credit Ratings |  | Counterparty |
|  |  |  |  | Millions |  |  |  |  |  |  |  |  |  |  |
| Powerton Station Units 5 and 6 |  | IL |  | $ | 133 |  |  | 64 | % |  | 1,538 |  |  | Coal |  | BB |  | NRG Energy, Inc. |
| Joliet Station Units 7 and 8 |  | IL |  | $ | 85 |  |  | 64 | % |  | 1,036 |  |  | Gas |  | BB |  | NRG Energy, Inc. |
| Shawville Station Units 1, 2, 3 and 4 |  | PA |  | $ | 77 |  |  | 100 | % |  | 596 |  |  | Gas |  | NR |  | REMA |

The credit exposure for lessors is partially mitigated through various credit enhancement mechanisms within the lease structures. These credit enhancement features vary from lease to lease. Upon the occurrence of certain defaults, indirect subsidiary companies 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
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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.
Additional factors that may impact future lease cash flows include, but are not limited to, new environmental legislation and regulation regarding air quality, water and other discharges in the process of generating electricity, market prices for fuel, electricity and capacity, overall financial condition of lease counterparties and their affiliates and the quality and condition of assets under lease.
Note 9. Trust Investments
Nuclear Decommissioning Trust (NDT) Fund
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 Power.
The following tables show the fair values and gross unrealized gains and losses for the securities held in the NDT Fund.

|  | As of March 31, 2019 |
|  | Cost |  | Gross Unrealized Gains |  | Gross Unrealized Losses |  | Fair Value |
|  | Millions |
| Equity Securities |  |  |  |  |  |  |  |
| Domestic | $ | 423 |  |  | $ | 183 |  |  | $ | (6 | ) |  | $ | 600 |  |
| International | 388 |  |  | 68 |  |  | (16 | ) |  | 440 |  |
| Total Equity Securities | 811 |  |  | 251 |  |  | (22 | ) |  | 1,040 |  |
| Available-for Sale Debt Securities |  |  |  |  |  |  |  |
| Government | 509 |  |  | 6 |  |  | (3 | ) |  | 512 |  |
| Corporate | 495 |  |  | 6 |  |  | (4 | ) |  | 497 |  |
| Total Available-for-Sale Debt Securities | 1,004 |  |  | 12 |  |  | (7 | ) |  | 1,009 |  |
| Total NDT Fund Investments | $ | 1,815 |  |  | $ | 263 |  |  | $ | (29 | ) |  | $ | 2,049 |  |

|  | As of December 31, 2018 |
|  | Cost |  | Gross Unrealized Gains |  | Gross Unrealized Losses |  | Fair Value |
|  | Millions |
| Equity Securities |  |  |  |  |  |  |  |
| Domestic | $ | 447 |  |  | $ | 153 |  |  | $ | (29 | ) |  | $ | 571 |  |
| International | 323 |  |  | 36 |  |  | (30 | ) |  | 329 |  |
| Total Equity Securities | 770 |  |  | 189 |  |  | (59 | ) |  | 900 |  |
| Available-for Sale Debt Securities |  |  |  |  |  |  |  |
| Government | 498 |  |  | 2 |  |  | (9 | ) |  | 491 |  |
| Corporate | 501 |  |  | 1 |  |  | (15 | ) |  | 487 |  |
| Total Available-for-Sale Debt Securities | 999 |  |  | 3 |  |  | (24 | ) |  | 978 |  |
| Total NDT Fund Investments | $ | 1,769 |  |  | $ | 192 |  |  | $ | (83 | ) |  | $ | 1,878 |  |

Net unrealized gains (losses) on debt securities of $3 million (after-tax) were included in Accumulated Other Comprehensive Loss on PSEG’s and Power’s Condensed Consolidated Balance Sheets as of March 31, 2019. The portion of net unrealized gains (losses) recognized during the first three months of 2019 related to equity securities still held at the end of March 31, 2019 was $88 million.
The amounts in the preceding tables do not include receivables and payables for NDT Fund transactions which have not settled
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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 |
|  | March 31, 2019 |  | December 31, 2018 |
|  | Millions |
| Accounts Receivable | $ | 16 |  |  | $ | 17 |  |
| Accounts Payable | $ | 14 |  |  | $ | 5 |  |

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 March 31, 2019 |  | As of December 31, 2018 |
|  | Less Than 12 Months |  | Greater Than 12 Months |  | Less Than 12 Months |  | Greater Than 12 Months |
|  | Fair Value |  | Gross Unrealized Losses |  | Fair Value |  | Gross Unrealized Losses |  | Fair Value |  | Gross Unrealized Losses |  | Fair Value |  | Gross Unrealized Losses |
|  | Millions |
| Equity Securities (A) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Domestic | $ | 45 |  |  | $ | (5 | ) |  | $ | 4 |  |  | $ | (1 | ) |  | $ | 147 |  |  | $ | (26 | ) |  | $ | 5 |  |  | $ | (3 | ) |
| International | 76 |  |  | (10 | ) |  | 20 |  |  | (6 | ) |  | 131 |  |  | (28 | ) |  | 5 |  |  | (2 | ) |
| Total Equity Securities | 121 |  |  | (15 | ) |  | 24 |  |  | (7 | ) |  | 278 |  |  | (54 | ) |  | 10 |  |  | (5 | ) |
| Available-for Sale Debt Securities |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Government (B) | 23 |  |  | — |  |  | 225 |  |  | (3 | ) |  | 51 |  |  | — |  |  | 317 |  |  | (9 | ) |
| Corporate (C) | 20 |  |  | — |  |  | 190 |  |  | (4 | ) |  | 150 |  |  | (5 | ) |  | 222 |  |  | (10 | ) |
| Total Available-for-Sale Debt Securities | 43 |  |  | — |  |  | 415 |  |  | (7 | ) |  | 201 |  |  | (5 | ) |  | 539 |  |  | (19 | ) |
| NDT Trust Investments | $ | 164 |  |  | $ | (15 | ) |  | $ | 439 |  |  | $ | (14 | ) |  | $ | 479 |  |  | $ | (59 | ) |  | $ | 549 |  |  | $ | (24 | ) |

(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 Power’s NDT investments in U.S. Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. These investments are guaranteed by the U.S. government or an agency of the U.S. government. Power also has investments in municipal bonds that are primarily in investment grade securities. It is not expected that these securities will settle for less than their amortized cost. Since Power does not intend to sell these securities nor will it be more-likely-than-not required to sell, Power does not consider these debt securities to be other-than-temporarily impaired as of March 31, 2019.

(C) | Debt Securities (Corporate)—Unrealized gains and losses on these securities are recorded in Accumulated Other Comprehensive Income (Loss). Power’s investments in corporate bonds are primarily in investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since Power does not intend to sell these securities nor will it be more-likely-than-not required to sell, Power does not consider these debt securities to be other-than-temporarily impaired as of March 31, 2019.

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

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
|  | Millions |
| Proceeds from NDT Fund Sales (A) | $ | 453 |  |  | $ | 372 |  |
| Net Realized Gains (Losses) on NDT Fund |  |  |  |
| Gross Realized Gains | $ | 45 |  |  | $ | 24 |  |
| Gross Realized Losses | (19 | ) |  | (12 | ) |
| Net Realized Gains (Losses) on NDT Fund (B) | $ | 26 |  |  | $ | 12 |  |
| Unrealized Gains (Losses) on Equity Securities in NDT Fund | 99 |  |  | (34 | ) |
| Net Gains (Losses) on NDT Fund Investments | $ | 125 |  |  | $ | (22 | ) |

(A)Includes activity in accounts related to the liquidation of funds being transitioned to new managers.
(B)The cost of these securities was determined on the basis of specific identification.
The NDT Fund debt securities held as of March 31, 2019 had the following maturities:

| Time Frame |  | Fair Value |
|  |  | Millions |
| Less than one year |  | $ | 13 |  |
| 1 - 5 years |  | 257 |  |
| 6 - 10 years |  | 215 |  |
| 11 - 15 years |  | 44 |  |
| 16 - 20 years |  | 71 |  |
| Over 20 years |  | 409 |  |
| Total NDT Available-for-Sale Debt Securities | $ | 1,009 |  |

Power periodically assesses individual debt securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily 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 in the value of these securities would be recognized in Accumulated Other Comprehensive Income (Loss) unless the securities are sold, in which case, any gain would be recognized in income. 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.”
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The following tables show the fair values, gross unrealized gains and losses and amortized cost basis for the securities held in the Rabbi Trust.

|  | As of March 31, 2019 |
|  | Cost |  | Gross Unrealized Gains |  | Gross Unrealized Losses |  | Fair Value |
|  | Millions |
| Domestic Equity Securities | $ | 22 |  |  | $ | 3 |  |  | $ | — |  |  | $ | 25 |  |
| Available-for-Sale Debt Securities |  |  |  |  |  |  |  |
| Government | 108 |  |  | 2 |  |  | — |  |  | 110 |  |
| Corporate | 97 |  |  | 2 |  |  | (1 | ) |  | 98 |  |
| Total Available-for-Sale Debt Securities | 205 |  |  | 4 |  |  | (1 | ) |  | 208 |  |
| Total Rabbi Trust Investments | $ | 227 |  |  | $ | 7 |  |  | $ | (1 | ) |  | $ | 233 |  |

|  | As of December 31, 2018 |
|  | Cost |  | Gross Unrealized Gains |  | Gross Unrealized Losses |  | Fair Value |
|  | Millions |
| Domestic Equity Securities | $ | 22 |  |  | $ | 1 |  |  | $ | — |  |  | $ | 23 |  |
| Available-for-Sale Debt Securities |  |  |  |  |  |  |  |
| Government | 110 |  |  | 1 |  |  | (2 | ) |  | 109 |  |
| Corporate | 96 |  |  | — |  |  | (4 | ) |  | 92 |  |
| Total Available-for-Sale Debt Securities | 206 |  |  | 1 |  |  | (6 | ) |  | 201 |  |
| Total Rabbi Trust Investments | $ | 228 |  |  | $ | 2 |  |  | $ | (6 | ) |  | $ | 224 |  |

Net unrealized gains (losses) on debt securities of $2 million (after-tax) were included in Accumulated Other Comprehensive Loss on PSEG’s Condensed Consolidated Balance Sheet as of March 31, 2019. The portion of net unrealized gains (losses) recognized during the first three months of 2019 related to equity securities still held at the end of March 31, 2019 was $3 million.
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 |
|  | March 31, 2019 |  | December 31, 2018 |
|  | Millions |
| Accounts Receivable | $ | 2 |  |  | $ | 2 |  |
| Accounts Payable | $ | 1 |  |  | $ | — |  |

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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 March 31, 2019 |  | As of December 31, 2018 |
|  | Less Than 12 Months |  | Greater Than 12 Months |  | Less Than 12 Months |  | Greater Than 12 Months |
|  | Fair Value |  | Gross Unrealized Losses |  | Fair Value |  | Gross Unrealized Losses |  | Fair Value |  | Gross Unrealized Losses |  | Fair Value |  | Gross Unrealized Losses |
|  | Millions |
| Available-for-Sale Debt Securities |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
| Government (A) | $ | — |  |  | $ | — |  |  | $ | 27 |  |  | $ | — |  |  | $ | 18 |  |  | $ | — |  |  | $ | 59 |  |  | $ | (2 | ) |
| Corporate (B) | 6 |  |  | — |  |  | 30 |  |  | (1 | ) |  | 50 |  |  | (3 | ) |  | 29 |  |  | (1 | ) |
| Total Available-for-Sale Debt Securities | 6 |  |  | — |  |  | 57 |  |  | (1 | ) |  | 68 |  |  | (3 | ) |  | 88 |  |  | (3 | ) |
| Rabbi Trust Investments | $ | 6 |  |  | $ | — |  |  | $ | 57 |  |  | $ | (1 | ) |  | $ | 68 |  |  | $ | (3 | ) |  | $ | 88 |  |  | $ | (3 | ) |

(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. These investments are guaranteed by the U.S. government or an agency of the U.S. government. PSEG also has investments in municipal bonds that are primarily in investment grade securities. It is not expected that these securities will settle for less than their amortized cost. Since PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell, PSEG does not consider these debt securities to be other-than-temporarily impaired as of March 31, 2019.

(B) | Debt Securities (Corporate)—Unrealized gains and losses on these securities are recorded in Accumulated Other Comprehensive Income (Loss). PSEG’s investments in corporate bonds are primarily in investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell, PSEG does not consider these debt securities to be other-than-temporarily impaired as of March 31, 2019.

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

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
|  | Millions |
| Proceeds from Rabbi Trust Sales (A) | $ | 44 |  |  | $ | 25 |  |
| Net Realized Gains (Losses) on Rabbi Trust: |  |  |  |
| Gross Realized Gains | $ | 1 |  |  | $ | 2 |  |
| Gross Realized Losses | (1 | ) |  | (2 | ) |
| Net Realized Gains (Losses) on Rabbi Trust (B) | — |  |  | — |  |
| Unrealized Gains (Losses) on Equity Securities in Rabbi Trust | 3 |  |  | — |  |
| Net Gains (Losses) on Rabbi Trust Investments | $ | 3 |  |  | $ | — |  |

(A)Includes activity in accounts related to the liquidation of funds being transitioned to new managers.
(B)The cost of these securities was determined on the basis of specific identification.
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The Rabbi Trust debt securities held as of March 31, 2019 had the following maturities:

| Time Frame |  | Fair Value |
|  |  | Millions |
| Less than one year |  | $ | — |  |
| 1 - 5 years |  | 33 |  |
| 6 - 10 years |  | 30 |  |
| 11 - 15 years |  | 10 |  |
| 16 - 20 years |  | 25 |  |
| Over 20 years |  | 110 |  |
| Total Rabbi Trust Available-for-Sale Debt Securities | $ | 208 |  |

PSEG periodically assesses individual debt securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily 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). 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 PSEG, PSE&G and Power are detailed as follows:

|  | As of |  | As of |
|  | March 31, 2019 |  | December 31, 2018 |
|  | Millions |
| PSE&G | $ | 46 |  |  | $ | 45 |  |
| Power | 59 |  |  | 56 |  |
| Other | 128 |  |  | 123 |  |
| Total Rabbi Trust Investments | $ | 233 |  |  | $ | 224 |  |

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.
In December 2018, PSEG amended certain provisions of its OPEB plans applicable to all current and future Medicare-eligible retirees and spouses who receive or will receive subsidized healthcare from PSEG. Effective January 1, 2021, the PSEG-sponsored Medicare-eligible plans will be replaced by a Medicare private exchange. For each Medicare-eligible retiree and spouse, PSEG will provide annual credits to a Health Reimbursement Arrangement, which can be used to pay for medical, prescription drug, and dental plan premiums, as well as certain out-of-pocket costs. The amendment resulted in a $559 million reduction in PSEG’s OPEB obligation as of December 31, 2018.
The following table provides the components of net periodic benefit costs 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.
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|  | Pension Benefits |  | OPEB |
|  | Three Months Ended |  | Three Months Ended |
|  | March 31, |  | March 31, |
|  | 2019 |  | 2018 |  | 2019 |  | 2018 |
|  | Millions |
| Components of Net Periodic Benefit (Credits) Costs |  |  |  |  |  |  |  |
| Service Cost (included in O&M Expense) | $ | 29 |  |  | $ | 32 |  |  | $ | 2 |  |  | $ | 4 |  |
| Non-Service Components of Pension and OPEB (Credits) Costs |  |  |  |  |  |  |  |
| Interest Cost | 58 |  |  | 52 |  |  | 11 |  |  | 16 |  |
| Expected Return on Plan Assets | (97 | ) |  | (110 | ) |  | (9 | ) |  | (10 | ) |
| Amortization of Net |  |  |  |  |  |  |  |
| Prior Service Cost | (5 | ) |  | (4 | ) |  | (32 | ) |  | — |  |
| Actuarial Loss | 27 |  |  | 21 |  |  | 13 |  |  | 16 |  |
| Non-Service Components of Pension and OPEB (Credits) Costs | (17 | ) |  | (41 | ) |  | (17 | ) |  | 22 |  |
| Total Benefit (Credits) Costs | $ | 12 |  |  | $ | (9 | ) |  | $ | (15 | ) |  | $ | 26 |  |

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

|  | Pension Benefits |  | OPEB |
|  | Three Months Ended |  | Three Months Ended |
|  | March 31, |  | March 31, |
|  | 2019 |  | 2018 |  | 2019 |  | 2018 |
|  | Millions |
| PSE&G | $ | 7 |  |  | $ | (8 | ) |  | $ | (16 | ) |  | $ | 17 |  |
| Power | 3 |  |  | (2 | ) |  | 1 |  |  | 8 |  |
| Other | 2 |  |  | 1 |  |  | — |  |  | 1 |  |
| Total Benefit (Credits) Costs | $ | 12 |  |  | $ | (9 | ) |  | $ | (15 | ) |  | $ | 26 |  |

During the three months ended March 31, 2019, PSEG contributed its entire 2019 annual planned contribution of $10 million into its OPEB plan.
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 Entity. 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 $28 million into its pension plan trusts during 2019. Servco’s pension-related revenues and costs were $7 million and $10 million for the three months ended March 31, 2019 and 2018, respectively. The OPEB-related revenues earned and costs incurred were $1 million for each of the three months ended March 31, 2019 and 2018.
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Note 11. Commitments and Contingent Liabilities
Guaranteed Obligations
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.
Power has unconditionally guaranteed payments to counterparties by 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.

Power is subject to

• | counterparty collateral calls related to commodity contracts, 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 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 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, Power would owe money to the counterparties).

Power believes the probability of this result is unlikely. For this reason, 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. 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, Power has also provided payment guarantees to third parties on behalf of its affiliated companies. These guarantees support various other non-commodity related contractual obligations.
The following table shows the face value of Power’s outstanding guarantees, current exposure and margin positions as of March 31, 2019 and December 31, 2018.

|  | As of |  | As of |
|  | March 31, 2019 |  | December 31, 2018 |
|  | Millions |
| Face Value of Outstanding Guarantees | $ | 1,854 |  |  | $ | 1,772 |  |
| Exposure under Current Guarantees | $ | 150 |  |  | $ | 198 |  |
| Letters of Credit Margin Posted | $ | 105 |  |  | $ | 115 |  |
| Letters of Credit Margin Received | $ | 29 |  |  | $ | 26 |  |
| Cash Deposited and Received: |  |  |  |
| Counterparty Cash Margin Deposited | $ | — |  |  | $ | — |  |
| Counterparty Cash Margin Received | $ | (1 | ) |  | $ | (10 | ) |
| Net Broker Balance Deposited (Received) | $ | 204 |  |  | $ | 403 |  |
| Additional Amounts Posted: |  |  |  |
| Other Letters of Credit | $ | 51 |  |  | $ | 52 |  |

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As part of determining credit exposure, 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 Power have posted letters of credit to support Power’s various other non-energy contractual and environmental obligations. See preceding table.
Environmental Matters
Passaic River
Historic operations of PSEG companies and the operations of hundreds of 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 as discussed as follows.
Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA)
The U.S. Environmental Protection Agency (EPA) has determined that a 17-mile stretch of the lower Passaic River from Newark to Clifton, New Jersey is a “Superfund” site under CERCLA and a comprehensive study of the entire 17 miles of the lower Passaic River needed to be performed. PSE&G and certain of its predecessors conducted operations at properties in this area of the Passaic River. The properties included one operating electric generating station (Essex Site), which was transferred to Power, one former generating station and four former manufactured gas plant (MGP) sites.
In early 2007, certain Potentially Responsible Parties (PRPs), including PSE&G and Power, formed a Cooperating Parties Group (CPG) and agreed to assume responsibility for conducting a Remedial Investigation and Feasibility Study (RI/FS) of the 17 miles of the lower Passaic River. The CPG has agreed to allocate, on an interim basis, the associated costs of the RI/FS among its members on the basis of a mutually agreed upon formula. For the purpose of this interim allocation, which has been revised as parties have exited the CPG, approximately 7.6 percent of the RI/FS costs are currently deemed attributable to PSE&G’s former MGP sites and approximately 1.9 percent is attributable to Power’s generating stations. These interim allocations are not binding on PSE&G or Power in terms of their respective shares of the costs that will be ultimately required to remediate the 17 miles of the lower Passaic River. PSEG has provided notice to insurers concerning this potential claim.
The CPG’s draft FS set forth various alternatives for remediating the lower Passaic River with an estimated cost to remediate the lower 17 miles of the Passaic River ranging from approximately $518 million to $3.2 billion on an undiscounted basis.
In March 2016, the EPA released its Record of Decision (ROD) for the EPA’s own Focused Feasibility Study (FFS) which requires the removal of 3.5 million cubic yards of sediment from the Passaic River’s lower 8.3 miles at an estimated cost of $2.3 billion on an undiscounted basis (ROD Remedy). The EPA estimated the total project length to be about 11 years, including a one year period of negotiation with the PRPs, three to four years to design the project and six years for implementation. Occidental Chemical Corporation (OCC), one of the PRPs, has commenced performance of the remedial design required by the ROD Remedy, reserving its right of cost contribution from all other PRPs.
In September 2017, the EPA concluded that an Agency-commenced allocation process for the Passaic River’s lower 8.3 miles should include only certain PRPs. The allocation is intended to lead to a consent decree in which certain of the PRPs agree to perform and pay for the remedial action under EPA oversight. The allocation process was delayed due to the partial federal government shutdown in late 2018 through early 2019, together with issues connected to OCC’s complaint in Federal District Court in Newark, and is now currently scheduled to continue into the summer of 2020.
In October 2018, the EPA Region 2 issued a Directive to the CPG instructing the CPG to focus the ongoing RI/FS evaluation on various adaptive management scenarios for remediation of the upper 9 miles of the Passaic River, which approach has been agreed to in concept by the EPA and the CPG. The Directive does not contain estimates for anticipated costs. Adaptive management focuses on removing targeted “hot spots” of contaminated sediments rather than removing all of the Passaic River’s sediments as in a “bank to bank” approach.
In a separate matter, two PRPs, Tierra Solutions, Inc. (Tierra) and Maxus Energy Corporation (Maxus), filed for Chapter 11 bankruptcy in Delaware Federal Bankruptcy Court. In June 2018, the trust representing the creditors in this proceeding filed a complaint asserting claims against the current and former parent entities of Tierra and Maxus, among other parties, for up to $14 billion. Any damages awarded may be used to fund, in part, the remediation costs of the lower 8.3 miles of the Passaic River. The creditor trust has reserved its right to file contribution claims against 28 PRPs, including PSEG. This matter is ongoing.
In June 2018, OCC filed a complaint in Federal District Court in Newark against various defendants, including PSE&G,
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seeking cost recovery and contribution under CERCLA for the remediation of the lower 8.3 miles of the Passaic River. The complaint does not quantify damages sought.
The Complaint alleges that “no single hazardous substance” is to blame for the contamination of the lower Passaic River and lists the eight Contaminants of Concern (COCs) identified by the EPA in the ROD. OCC alleges PSE&G is responsible for a portion of six of the eight COCs. PSE&G cannot predict the outcome of this matter.
Based upon the estimated cost of the ROD Remedy and PSEG’s estimate of PSE&G’s and Power’s shares of that cost, as of March 31, 2019, PSEG has accrued approximately $57 million. Of this amount, PSE&G has accrued $46 million as an Environmental Costs Liability and a corresponding Regulatory Asset based on its continued ability to recover such costs in its rates. Power has accrued $11 million as an Other Noncurrent Liability with the corresponding O&M Expense recorded in prior years when the liability was accrued.
The EPA has broad authority to implement its selected remedy through the ROD and PSEG cannot at this time predict how the implementation of the ROD might impact PSE&G’s and Power’s ultimate liability. Until (i) the RI/FS, which covers the entire 17 miles of the lower Passaic River, is finalized either in whole or in part, (ii) an agreement by the PRPs to perform either the ROD Remedy as issued, or an amended ROD Remedy determined through negotiation or litigation, and an agreed upon remedy for the remaining 8.7 miles of the river, are reached, (iii) PSE&G’s and Power’s respective shares of the costs, both in the aggregate as well as individually, are determined, and (iv) PSE&G’s continued 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 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.
Natural Resource Damage Claims
In 2003, the New Jersey Department of Environmental Protection (NJDEP) directed PSEG, PSE&G and 56 other PRPs to arrange for a natural resource damage assessment and interim compensatory restoration of natural resource injuries along the lower Passaic River and its tributaries pursuant to the New Jersey Spill Compensation and Control Act. The NJDEP alleged that hazardous substances had been discharged from the Essex Site and the Harrison Site. The NJDEP estimated the cost of interim natural resource injury restoration activities along the lower Passaic River at approximately $950 million. In 2007, agencies of the U.S. Department of Commerce and the U.S. Department of the Interior (the Passaic River federal trustees) sent letters to PSE&G and other PRPs inviting participation in an assessment of injuries to natural resources that the agencies intended to perform. In 2008, PSEG and a number of other PRPs agreed to share certain immaterial costs the trustees have incurred and will incur going forward, and to work with the trustees to explore whether some or all of the trustees’ claims can be resolved in a cooperative fashion. That effort is continuing. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter.
Newark Bay Study Area
The EPA has established the Newark Bay Study Area, which it defines as Newark Bay and portions of the Hackensack River, the Arthur Kill and the Kill Van Kull. In August 2006, the EPA sent PSEG and 11 other entities notices that it considered each of the entities to be a PRP with respect to contamination in the Study Area. The notice letter requested that the PRPs fund an EPA-approved study in the Newark Bay Study Area. The notice stated the EPA’s belief that hazardous substances were released from sites owned by PSEG companies and located on the Hackensack River, including two electric generating stations (Hudson and Kearny sites) and one former MGP site. PSEG has participated in and partially funded the second phase of this study. Notices to fund the next phase of the study have been received but PSEG has not consented to fund the third phase. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter. In December 2018, Power completed the sale of the site of the Hudson electric generating station. Power contractually transferred all land rights and structures on the site to a third party purchaser, along with the assumption of the environmental liabilities for the site.
MGP Remediation Program
PSE&G is working with the 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 $353 million and $404 million on an undiscounted basis through 2021, including its $46 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 $353 million as of March 31, 2019. Of this amount, $52 million was recorded in Other Current Liabilities and $301 million was reflected as Environmental Costs in Noncurrent Liabilities. PSE&G has recorded a $353 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. NJDEP, PSEG and EPA representatives have had discussions regarding to what extent
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sampling in the Passaic River is required to delineate coal tar from MGP sites that abut the Passaic River Superfund site. PSEG cannot determine at this time whether this will have an impact on the Passaic River Superfund remedy.
Clean Water Act (CWA) Permit Renewals
Pursuant to the Federal Water Pollution Control Act, National Pollutant Discharge Elimination System permits expire within five years of their effective date. In order to renew these permits, but allow a plant to continue to operate, an owner or operator must file a permit application no later than six months prior to expiration of the permit. States with delegated federal authority for this program manage these permits. 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 May 2014, the EPA issued a final cooling water intake rule that 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 has structured the rule so that each state Permitting Director will continue to consider renewal permits for existing
power facilities on a case by case basis, based on studies related to impingement mortality and entrainment by the facilities seeking renewal permits.
Several environmental organizations and certain energy industry groups have filed suit under the CWA and the Endangered Species Act. The cases were consolidated at the Second Circuit, and in July 2018 the Second Circuit upheld the EPA’s final cooling water intake rule. The Court’s decision allows Permitting Directors to continue to issue permits in accordance with the flexible, site-specific provisions of the final rule.
In June 2016, the NJDEP issued a final NJPDES permit for Salem. The final permit does not mandate specific service water system modifications, but consistent with Section 316 (b) of the CWA, it requires additional studies and the selection of technology to address impingement for the service water system. In July 2016, the Delaware Riverkeeper Network (Riverkeeper) filed a request challenging the NJDEP’s issuance of the final NJPDES renewal permit for Salem. NJDEP has granted the hearing request, but it has not yet been scheduled. The Riverkeeper’s filing does not change the effective date of the permit. If the Riverkeeper’s challenge were successful, Power may be required to incur additional costs to comply with the CWA. Potential cooling water system modification costs could be material and could adversely impact the economic competitiveness of this facility.
State permitting decisions at Bridgeport and possibly New Haven could also have a material impact on Power’s ability to renew permits at its existing larger once-through cooled plants without making significant upgrades to existing intakes and cooling systems.
Power is unable to predict the outcome of these permitting decisions and the effect, if any, that they may have on Power’s future capital requirements, financial condition or results of operations.
Power is actively engaged with the Connecticut Department of Energy and Environmental Protection (CTDEEP) regarding renewal of the current permit for the cooling water intake structure at Bridgeport Harbor Station Unit 3 (BH3). To address compliance with the EPA’s CWA Section 316(b) final rule, Power has proposed to continue to operate BH3 without making the capital expenditures for modification to the existing intake structure and retire BH3 in 2021, which is four years earlier than the previously estimated useful life ending in 2025. Power is currently awaiting action by the CTDEEP to issue a draft and then a final permit.
Power has entered into a Community Environmental Benefit Agreement (CEBA) with the City of Bridgeport, Connecticut and local community organizations. That CEBA provides that Power would retire BH3 early if all of its conditions precedent occur, which include receipt of all final permits to build and operate a proposed new combined cycle generating facility on the same site that BH3 currently operates. Absent those conditions being met, and the permit for the cooling water intake structure referred to above not being issued, Power may seek to operate BH3 through the previously estimated useful life.
In February 2016, the proposed new generating facility at Bridgeport Harbor was awarded a capacity obligation. The Connecticut Siting Council issued an order to approve siting BH5. Operations are expected to begin in mid-2019. Power’s obligations under the CEBA are being monitored regularly and carried out as needed.
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 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, with PSE&G owning the portion
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of the cables located in New Jersey and Con Edison owning the portion of the cables located in New York. The NJDEP declared an emergency and an emergency response action was undertaken to investigate, contain, remediate and stop the fluid discharge; to assess, repair and restore the cables to good working order, if feasible; and to restore the property. The regulatory agencies overseeing the emergency response, including the U.S. Coast Guard, the NJDEP and the Army Corps of Engineers, issued multiple notices, orders and directives to the various parties related to this matter and the parties may also be subject to the assessment of civil penalties related to the discharge and response. The U.S. Coast Guard transitioned control of the federal response to the EPA in May 2018. In August 2018, the EPA ended the federal response to the matter. The response has now transitioned to the NJDEP site remediation program.
The impacted cable was repaired in late September 2017; however, small amounts of residual dielectric fluid believed to be contained within the marina sediment continue to appear on the surface and response actions related to the fluid discharge are ongoing, although at a significantly reduced scale. PSE&G remains concerned about future leaks and potential environmental impacts as a result of reintroduction of fluid back into these lines and has determined that retirement of the affected facilities is appropriate. PSE&G has been unable to reach an agreement with Con Edison and, as a result, in May 2018, PSE&G filed an action at FERC to resolve the matter. FERC dismissed PSE&G’s Complaint against Con Edison in September 2018 and PSE&G has challenged FERC’s decision. Also ongoing is the lawsuit in federal court 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 these costs through regulatory proceedings.
Basic Generation Service (BGS) and Basic Gas Supply Service (BGSS)
PSE&G obtains its electric supply requirements through the annual New Jersey BGS auctions for two categories of customers who choose not to purchase electric supply from third-party suppliers. The first category, which represents about 80% 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 Agreement with the winners of these BGS auctions following the BPU’s approval of the auction results. PSE&G has entered into contracts with winning BGS suppliers, including Power, to purchase BGS for PSE&G’s load requirements. The winners of the auction (including Power) are 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.
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, 2019 is $281.78 per MW-day, replacing the BGS-CIEP auction year price ending May 31, 2019 of $287.76 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 |  |
|  | 2016 |  | 2017 |  | 2018 |  | 2019 |  |
| 36-Month Terms Ending | May 2019 |  | May 2020 |  | May 2021 |  | May 2022 | (A) |
| Load (MW) | 2,800 |  | 2,800 |  | 2,900 |  | 2,800 |  |
| $ per MWh | $96.38 |  | $90.78 |  | $91.77 |  | $98.04 |  |

(A) | Prices set in the 2019 BGS auction will become effective on June 1, 2019 when the 2016 BGS auction agreements expire.

Power seeks to mitigate volatility in its results by contracting in advance for the sale of most of its anticipated electric output as well as its anticipated fuel needs. As part of its objective, Power has entered into contracts to directly supply PSE&G and other New Jersey electric distribution companies with a portion of their respective BGS requirements through the New Jersey BGS auction process, described above.
PSE&G has a full-requirements contract with Power to meet the gas supply requirements of PSE&G’s gas customers. 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
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through the BGSS tariff. Current plans call for 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.
Minimum Fuel Purchase Requirements
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. Power’s nuclear fuel commitments cover approximately 100% of its estimated uranium, enrichment and fabrication requirements through 2020 and a significant portion through 2021 at Salem, Hope Creek and Peach Bottom.
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, Power can use the gas to supply its fossil generating stations in New Jersey.
Power also has various long-term fuel purchase commitments for coal through 2023 to support its fossil generation stations.
As of March 31, 2019, the total minimum purchase requirements included in these commitments were as follows:

| Fuel Type |  | Power's Share of Commitments through 2023 |
|  |  | Millions |
| Nuclear Fuel |  |  |
| Uranium |  | $ | 221 |  |
| Enrichment |  | $ | 336 |  |
| Fabrication |  | $ | 157 |  |
| Natural Gas |  | $ | 1,121 |  |
| Coal |  | $ | 380 |  |

Pending FERC Matters
In June 2015, Hudson Power Transmission Developers, LLC (Hudson Power), formerly known as Transource LLC, a merchant transmission developer, filed a complaint against PJM claiming that PJM wrongfully refused to provide data and a transparent process for evaluating transmission network upgrade requests that the transmission developer had submitted to PJM. Although not named as a respondent, the complaint identifies PSE&G as one of the companies claimed to have been involved. In January 2018, a FERC administrative law judge (ALJ) issued an order generally finding that PJM and transmission owners, including PSE&G, did not engage in wrongful conduct. In addition, the developer’s assertion of an entitlement to monetary damages was expressly denied. However, in a determination disputed by PSE&G, the order found that the PJM process lacked transparency. The judge’s order has been briefed by all parties for additional determinations by FERC. We are unable to predict the outcome of these proceedings.
PSE&G has also received requests for information and a Notice of Investigation from FERC’s Office of Enforcement concerning a transmission project. PSE&G has retained outside counsel to assist with an internal investigation. 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.
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 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 Power withheld money owed to Durr and that Power’s intentional conduct led to the inability of Durr to obtain prospective contracts. Power intends to vigorously defend against these allegations. 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. 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, Power cannot predict the outcome of this matter.
Newark Customer Incident
On the morning of July 5, 2018, PSE&G discontinued electricity to the home of a customer residing in Newark because of outstanding arrears on that customer’s account. Subsequent to the discontinuation of electricity, that customer died on the
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afternoon of July 5th. The family of the customer, who was on hospice care, raised allegations in the media regarding PSE&G’s conduct surrounding the discontinuation and restoration of electricity to the home of the customer, claiming that the discontinuation of electric service prevented the customer from using life sustaining medical equipment. The BPU initiated an investigation into the matter and that investigation is ongoing. In addition, PSE&G received a grand jury subpoena from the Essex County Prosecutor’s Office (ECPO) for records and correspondence between PSE&G and the customer. PSE&G is fully cooperating with the BPU and the ECPO in both proceedings. PSEG cannot predict the outcome of the pending proceedings regarding this incident at this time.
The PSEG Board of Directors (PSEG Board) retained outside counsel to conduct an independent investigation of the facts surrounding this incident with the full support and cooperation of management. The independent investigation concluded that the disconnection itself was not improper; however, it did identify issues related to PSE&G’s response once it was notified of the disconnection. The PSEG Board reviewed and considered the findings and conclusions of the investigation and PSE&G’s proposed corrective actions. PSE&G’s progress on implementation of the corrective actions will continue to be overseen by the PSEG Board.
Caithness Energy, L.L.C. (Caithness)
In August 2018, Caithness, a Long Island power plant developer, filed a complaint in federal district court in the Eastern District of New York against PSEG and PSEG LI alleging violations of state and federal antitrust laws and a claim of intentional interference of prospective business relations. Caithness alleges that PSEG and PSEG LI interfered with LIPA’s consideration of the Caithness proposal for a 750 MW combined cycle generation project that was identified as a finalist for a Request For Proposal issued by LIPA. In addition, Caithness claims that PSEG and PSEG LI induced LIPA to agree to eliminate the proposed project as a potential competitor to other PSEG affiliates with power supply operations. The complaint alleges hundreds of millions of dollars of harm and seeks treble and punitive damages. PSEG intends to vigorously defend against these allegations. Based upon the preliminary nature of this matter, a loss is not considered probable nor is the amount of loss, if any, estimable as of March 31, 2019.
Hudson Power
In January 2019, Hudson Power filed a complaint against PJM, PSE&G and three other transmission owners in Pennsylvania state court. Hudson Power has sued the transmission owner defendants for fraud and intentional misrepresentation relating to information provided to PJM and FERC regarding the costs of upgrades for Hudson Power’s proposed project. These allegations appear to be based on alleged conduct that is the subject of the Hudson Power proceeding discussed under “Pending FERC Matters.” This action was removed to federal court in the Eastern District of Pennsylvania in February 2019. In light of the FERC proceeding, the federal court granted a motion to stay the federal proceeding until the conclusion of the FERC proceeding. Based upon the preliminary nature of this matter, a loss is not considered probable nor is the amount of loss, if any, estimable as of March 31, 2019.
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 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 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 Power’s results of operations or liquidity for any particular reporting period.
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Note 12. Debt and Credit Facilities
Long-Term Debt Financing Transactions
The following long-term debt transactions occurred in the three months ended March 31, 2019:
PSEG
PSEG repaid a $350 million term loan at an interest rate of 1 month LIBOR + 0.80% that was scheduled to mature in June 2019.
Power
Power executed an extension of the letter of credit backing $44 million of Pennsylvania Economic Development Financing Authority Variable Rate Demand Bonds. The existing letter of credit, which was scheduled to expire in November 2019, has now been extended through March 2022.
Short-Term Liquidity
PSEG meets its short-term liquidity requirements, as well as those of Power, primarily with cash and through the issuance of commercial paper. 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 March 31, 2019, the total available credit capacity was $2.9 billion.
As of March 31, 2019, no single institution represented more than 9% of the total commitments in the credit facilities.
As of March 31, 2019, total credit capacity was in excess of the total anticipated maximum liquidity requirements over PSEG’s 12-month planning horizon.
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. The total credit facilities and available liquidity as of March 31, 2019 were as follows:

|  |  | As of March 31, 2019 |  |  |  |  |
| Company/Facility |  | Total Facility |  | Usage (D) |  | Available Liquidity |  | Expiration Date |  | Primary Purpose |
|  |  | Millions |  |  |  |  |
| PSEG |  |  |  |  |  |  |  |  |  |  |
| 5-year Credit Facilities (A) |  | $ | 1,500 |  |  | $ | 802 |  |  | $ | 698 |  |  | Mar 2023 |  | Commercial Paper Support/Funding/Letters of Credit |
| Total PSEG |  | $ | 1,500 |  |  | $ | 802 |  |  | $ | 698 |  |  |  |  |  |
| PSE&G |  |  |  |  |  |  |  |  |  |  |
| 5-year Credit Facility (B) |  | $ | 600 |  |  | $ | 380 |  |  | $ | 220 |  |  | Mar 2023 |  | Commercial Paper Support/Funding/Letters of Credit |
| Total PSE&G |  | $ | 600 |  |  | $ | 380 |  |  | $ | 220 |  |  |  |  |  |
| Power |  |  |  |  |  |  |  |  |  |  |
| 3-year Letter of Credit Facilities |  | $ | 200 |  |  | $ | 104 |  |  | $ | 96 |  |  | Sept 2021 |  | Letters of Credit |
| 5-year Credit Facilities (C) |  | 1,900 |  |  | 39 |  |  | 1,861 |  |  | Mar 2023 |  | Funding/Letters of Credit |
| Total Power |  | $ | 2,100 |  |  | $ | 143 |  |  | $ | 1,957 |  |  |  |  |  |
| Total |  | $ | 4,200 |  |  | $ | 1,325 |  |  | $ | 2,875 |  |  |  |  |  |

(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) | 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 March 31, 2019, PSEG had $787 million outstanding at a weighted average interest rate of 2.92%. PSE&G had $364 million outstanding at a weighted average interest rate of 2.80% under its Commercial Paper Program as of March 31, 2019.

Except as otherwise noted in the table above, in March 2019, PSEG, PSE&G and Power and their respective lenders agreed to
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extend the expiration dates on their credit agreements from March 2022 to March 2023.
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, 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 effective as cash flow or fair value hedges. 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.
Commodity Prices
Within PSEG and its affiliate companies, Power has the most exposure to commodity price risk. 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. Power uses a variety of 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 Power’s expected generation. 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, 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.
Fair Value Hedges
PSEG enters into fair value hedges to convert fixed-rate debt into variable-rate debt. The changes in fair value of the interest rate swaps are fully offset by changes in the fair value of the underlying forecasted interest payments of the debt. There were no outstanding interest rate swaps as of March 31, 2019 or December 31, 2018.
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. As of March 31, 2019, PSEG had interest rate hedges outstanding totaling $900 million that were executed during the first quarter of 2019. PSEG executed interest rate swaps of $700 million that converted PSEG’s $700 million variable rate term loan due November 2020 into a fixed rate loan and $200 million of forward starting swaps that hedge a portion of PSEG’s anticipated issuances.
The fair value of these hedges was $(5) million as of March 31, 2019 and there were no outstanding interest rate hedges as of December 31, 2018. The Accumulated Other Comprehensive Income (Loss) (after tax) related to outstanding and terminated interest rate derivatives designated as cash flow hedges was $(5) million and $(1) million as of March 31, 2019 and December 31, 2018, respectively. The after-tax unrealized losses on these hedges expected to be reclassified to earnings during the next 12 months are immaterial.
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 Power and PSEG. For additional information see Note 14. Fair Value Measurements.
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The following tabular disclosure does not include the offsetting of trade receivables and payables.

|  |  | As of March 31, 2019 |
|  |  | Power (A) |  | PSEG (A) |  | Consolidated |
|  |  | Not Designated |  |  |  |  |  | Cash Flow Hedges |  |  |
| Balance Sheet Location |  | Energy- Related Contracts |  | Netting (B) |  | Total Power |  | Interest Rate Swaps |  | Total Derivatives |
|  |  | Millions |
| Derivative Contracts |  |  |  |  |  |  |  |  |  |  |
| Current Assets |  | $ | 346 |  |  | $ | (327 | ) |  | $ | 19 |  |  | $ | 1 |  |  | $ | 20 |  |
| Noncurrent Assets |  | 180 |  |  | (176 | ) |  | 4 |  |  | — |  |  | 4 |  |
| Total Mark-to-Market Derivative Assets |  | $ | 526 |  |  | $ | (503 | ) |  | $ | 23 |  |  | $ | 1 |  |  | $ | 24 |  |
| Derivative Contracts |  |  |  |  |  |  |  |  |  |  |
| Current Liabilities |  | $ | (396 | ) |  | $ | 383 |  |  | $ | (13 | ) |  | $ | — |  |  | $ | (13 | ) |
| Noncurrent Liabilities |  | (169 | ) |  | 168 |  |  | (1 | ) |  | (6 | ) |  | (7 | ) |
| Total Mark-to-Market Derivative (Liabilities) |  | $ | (565 | ) |  | $ | 551 |  |  | $ | (14 | ) |  | $ | (6 | ) |  | $ | (20 | ) |
| Total Net Mark-to-Market Derivative Assets (Liabilities) |  | $ | (39 | ) |  | $ | 48 |  |  | $ | 9 |  |  | $ | (5 | ) |  | $ | 4 |  |

|  |  | As of December 31, 2018 |
|  |  | Power (A) |  | Consolidated |
|  |  | Not Designated |  |  |  |  |  |  |
| Balance Sheet Location |  | Energy- Related Contracts |  | Netting (B) |  | Total Power |  | Total Derivatives |
|  |  | Millions |
| Derivative Contracts |  |  |  |  |  |  |  |  |
| Current Assets |  | $ | 426 |  |  | $ | (415 | ) |  | $ | 11 |  |  | $ | 11 |  |
| Noncurrent Assets |  | 137 |  |  | (136 | ) |  | 1 |  |  | 1 |  |
| Total Mark-to-Market Derivative Assets |  | $ | 563 |  |  | $ | (551 | ) |  | $ | 12 |  |  | $ | 12 |  |
| Derivative Contracts |  |  |  |  |  |  |  |  |
| Current Liabilities |  | $ | (521 | ) |  | $ | 510 |  |  | $ | (11 | ) |  | $ | (11 | ) |
| Noncurrent Liabilities |  | (198 | ) |  | 194 |  |  | (4 | ) |  | (4 | ) |
| Total Mark-to-Market Derivative (Liabilities) |  | $ | (719 | ) |  | $ | 704 |  |  | $ | (15 | ) |  | $ | (15 | ) |
| Total Net Mark-to-Market Derivative Assets (Liabilities) |  | $ | (156 | ) |  | $ | 153 |  |  | $ | (3 | ) |  | $ | (3 | ) |

(A) | Substantially all of 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 March 31, 2019 and December 31, 2018.

(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 or 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 March 31, 2019 and December 31, 2018, Power had net cash collateral/margin payments to counterparties of $203 million and $393 million, respectively. Of these net cash/collateral margin payments, $48 million as of March 31, 2019 and $153 million as December 31, 2018 were netted against the corresponding net derivative contract positions. Of the $48 million as of March 31, 2019, $(9) million was netted against noncurrent assets and $57 million was netted against current liabilities. Of the $153 million as of December 31, 2018, $(2) million was netted against current assets, $(3) million was netted against noncurrent assets, $96 million was netted against current liabilities and $62 million was netted against noncurrent liabilities.

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Certain of Power’s derivative instruments contain provisions that require Power to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon 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 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 Power would represent a three level downgrade from its current S&P or Moody’s ratings. 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. 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 $16 million and $22 million as of March 31, 2019 and December 31, 2018, respectively. As of March 31, 2019 and December 31, 2018, Power had the contractual right of offset of $4 million and $7 million, respectively, related to derivative instruments that are assets with the same counterparty under master agreements and net of margin posted. If Power had been downgraded to a below investment grade rating, it would have had additional collateral obligations of $12 million and $15 million as of March 31, 2019 and December 31, 2018, respectively, related to its derivatives, net of the contractual right of offset under master agreements and the application of collateral.
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 ended March 31, 2019 and 2018:

| Derivatives in Cash Flow Hedging Relationships |  | Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives |  | Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income |  | Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income |
|  | Three Months Ended |  |  |  | Three Months Ended |
|  | March 31, |  |  |  | March 31, |
|  | 2019 |  | 2018 |  |  |  | 2019 |  | 2018 |
|  |  | Millions |  |  |  | Millions |
| PSEG |  |  |  |  |  |  |  |  |  |  |
| Interest Rate Swaps |  | $ | (5 | ) |  | $ | — |  |  | Interest Expense |  | $ | — |  |  | $ | — |  |
| Total PSEG |  | $ | (5 | ) |  | $ | — |  |  |  |  | $ | — |  |  | $ | — |  |

The effect of interest rate cash flow hedges is recorded in Interest Expense in PSEG’s Condensed Consolidated Statement of Operations. For the three months ended March 31, 2019 and 2018, the amount of gain or loss on interest rate hedges reclassified from Accumulated Other Comprehensive Income (Loss) into income was immaterial.
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, 2017 |  | $ | — |  |  | $ | — |  |
| Loss Recognized in AOCI |  | (2 | ) |  | (1 | ) |
| Less: Loss Reclassified into Income |  | — |  |  | — |  |
| Balance as of December 31, 2018 |  | $ | (2 | ) |  | $ | (1 | ) |
| Loss Recognized in AOCI |  | (5 | ) |  | (4 | ) |
| Less: Loss Reclassified into Income |  | — |  |  | — |  |
| Balance as of March 31, 2019 |  | $ | (7 | ) |  | $ | (5 | ) |

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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 ended March 31, 2019 and 2018, respectively. 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 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 Gain (Loss) Recognized in Income on Derivatives |  | Pre-Tax Gain (Loss) Recognized in Income on Derivatives |
|  |  |  |  | Three Months Ended |
|  |  |  |  | March 31, |
|  |  |  |  | 2019 |  | 2018 |
|  |  |  | Millions |
| PSEG and Power |  |  |  |  |  |  |
| Energy-Related Contracts |  | Operating Revenues |  | $ | 139 |  |  | $ | 40 |  |
| Energy-Related Contracts |  | Energy Costs |  | (13 | ) |  | (8 | ) |
| Total PSEG and Power |  |  |  | $ | 126 |  |  | $ | 32 |  |

The following table summarizes the net notional volume purchases/(sales) of open derivative transactions by commodity as of March 31, 2019 and December 31, 2018.

| Type |  | Notional |  | Total |  | PSEG |  | Power |  | PSE&G |
|  |  |  |  | Millions |
| As of March 31, 2019 |  |  |  |  |  |  |  |  |  |  |
| Natural Gas |  | Dekatherm (Dth) |  | 353 |  |  | — |  |  | 353 |  |  | — |  |
| Electricity |  | MWh |  | (61 | ) |  | — |  |  | (61 | ) |  | — |  |
| Financial Transmission Rights (FTRs) |  | MWh |  | 10 |  |  | — |  |  | 10 |  |  | — |  |
| Interest Rate Swaps |  | U.S. Dollars |  | 900 |  |  | 900 |  |  | — |  |  | — |  |
| As of December 31, 2018 |  |  |  |  |  |  |  |  |  |  |
| Natural Gas |  | Dth |  | 358 |  |  | — |  |  | 358 |  |  | — |  |
| Electricity |  | MWh |  | (74 | ) |  | — |  |  | (74 | ) |  | — |  |
| FTRs |  | MWh |  | 18 |  |  | — |  |  | 18 |  |  | — |  |

Credit Risk
Credit risk relates to the risk of loss that 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 Power’s and PSEG’s financial condition, results of operations or net cash flows.
The following table provides information on Power’s credit risk from wholesale counterparties, net of collateral, as of March 31, 2019. 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 Power’s credit risk by credit rating of the counterparties.
As of March 31, 2019, 99% of the net credit exposure for 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).
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| Rating |  | Current Exposure |  | Securities held as Collateral |  | Net Exposure |  | Number of Counterparties >10% |  | Net Exposure of Counterparties >10% |  |
|  |  | Millions |  |  |  | Millions |  |
| Investment Grade |  | $ | 255 |  |  | $ | 15 |  |  | $ | 240 |  |  | 1 |  |  | $ | 166 |  | (A) |
| Non-Investment Grade |  | 2 |  |  | 1 |  |  | 1 |  |  | — |  |  | — |  |  |
| Total |  | $ | 257 |  |  | $ | 16 |  |  | $ | 241 |  |  | 1 |  |  | $ | 166 |  |  |

(A) | Represents net exposure of $166 million with PSE&G.

As of March 31, 2019, collateral held from counterparties where Power had credit exposure included $1 million in cash collateral and $15 million in letters of credit.
As of March 31, 2019, Power had 145 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 March 31, 2019, primarily all of the posted collateral was 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 March 31, 2019, PSE&G had no net credit exposure with suppliers, including 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 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 Power’s respective assets and (liabilities) measured at fair value on a recurring basis as of March 31, 2019 and December 31, 2018, 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 Power.
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|  |  | Recurring Fair Value Measurements as of March 31, 2019 |
| Description |  | Total |  | Netting (D) |  | Quoted Market Prices for Identical Assets (Level 1) |  | Significant Other Observable Inputs (Level 2) |  | Significant Unobservable Inputs (Level 3) |
|  |  | Millions |
| PSEG |  |  |  |  |  |  |  |  |  |  |
| Assets: |  |  |  |  |  |  |  |  |  |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | 23 |  |  | $ | (503 | ) |  | $ | 11 |  |  | $ | 514 |  |  | $ | 1 |  |
| Interest Rate Swaps (B) |  | $ | 1 |  |  | $ | — |  |  | $ | — |  |  | $ | 1 |  |  | $ | — |  |
| NDT Fund (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 1,040 |  |  | $ | — |  |  | $ | 1,039 |  |  | $ | 1 |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 182 |  |  | $ | — |  |  | $ | — |  |  | $ | 182 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 330 |  |  | $ | — |  |  | $ | — |  |  | $ | 330 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 497 |  |  | $ | — |  |  | $ | — |  |  | $ | 497 |  |  | $ | — |  |
| Rabbi Trust (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 25 |  |  | $ | — |  |  | $ | 25 |  |  | $ | — |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 68 |  |  | $ | — |  |  | $ | — |  |  | $ | 68 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 42 |  |  | $ | — |  |  | $ | — |  |  | $ | 42 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 98 |  |  | $ | — |  |  | $ | — |  |  | $ | 98 |  |  | $ | — |  |
| Liabilities: |  |  |  |  |  |  |  |  |  |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | (14 | ) |  | $ | 551 |  |  | $ | (6 | ) |  | $ | (556 | ) |  | $ | (3 | ) |
| Interest Rate Swaps (B) |  | $ | (6 | ) |  | $ | — |  |  | $ | — |  |  | $ | (6 | ) |  | $ | — |  |
| PSE&G |  |  |  |  |  |  |  |  |  |  |
| Assets: |  |  |  |  |  |  |  |  |  |  |
| Rabbi Trust (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 5 |  |  | $ | — |  |  | $ | 5 |  |  | $ | — |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 13 |  |  | $ | — |  |  | $ | — |  |  | $ | 13 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 8 |  |  | $ | — |  |  | $ | — |  |  | $ | 8 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 20 |  |  | $ | — |  |  | $ | — |  |  | $ | 20 |  |  | $ | — |  |
| Power |  |  |  |  |  |  |  |  |  |  |
| Assets: |  |  |  |  |  |  |  |  |  |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | 23 |  |  | $ | (503 | ) |  | $ | 11 |  |  | $ | 514 |  |  | $ | 1 |  |
| NDT Fund (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 1,040 |  |  | $ | — |  |  | $ | 1,039 |  |  | $ | 1 |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 182 |  |  | $ | — |  |  | $ | — |  |  | $ | 182 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 330 |  |  | $ | — |  |  | $ | — |  |  | $ | 330 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 497 |  |  | $ | — |  |  | $ | — |  |  | $ | 497 |  |  | $ | — |  |
| Rabbi Trust (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 6 |  |  | $ | — |  |  | $ | 6 |  |  | $ | — |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 17 |  |  | $ | — |  |  | $ | — |  |  | $ | 17 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 11 |  |  | $ | — |  |  | $ | — |  |  | $ | 11 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 25 |  |  | $ | — |  |  | $ | — |  |  | $ | 25 |  |  | $ | — |  |
| Liabilities: |  |  |  |  |  |  |  |  |  |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | (14 | ) |  | $ | 551 |  |  | $ | (6 | ) |  | $ | (556 | ) |  | $ | (3 | ) |

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|  |  | Recurring Fair Value Measurements as of December 31, 2018 |
| Description |  | Total |  | Netting (D) |  | Quoted Market Prices for Identical Assets (Level 1) |  | Significant Other Observable Inputs (Level 2) |  | Significant Unobservable Inputs (Level 3) |
|  |  | Millions |
| PSEG |  |  |  |  |  |  |  |  |  |  |
| Assets: |  |  |  |  |  |  |  |  |  |  |
| Cash Equivalents (E) |  | $ | 100 |  |  | $ | — |  |  | $ | 100 |  |  | $ | — |  |  | $ | — |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | 12 |  |  | $ | (551 | ) |  | $ | 29 |  |  | $ | 527 |  |  | $ | 7 |  |
| NDT Fund (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 900 |  |  | $ | — |  |  | $ | 898 |  |  | $ | 2 |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 171 |  |  | $ | — |  |  | $ | — |  |  | $ | 171 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 320 |  |  | $ | — |  |  | $ | — |  |  | $ | 320 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 487 |  |  | $ | — |  |  | $ | — |  |  | $ | 487 |  |  | $ | — |  |
| Rabbi Trust (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 23 |  |  | $ | — |  |  | $ | 23 |  |  | $ | — |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 69 |  |  | $ | — |  |  | $ | — |  |  | $ | 69 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 40 |  |  | $ | — |  |  | $ | — |  |  | $ | 40 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 92 |  |  | $ | — |  |  | $ | — |  |  | $ | 92 |  |  | $ | — |  |
| Liabilities: |  |  |  |  |  |  |  |  |  |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | (15 | ) |  | $ | 704 |  |  | $ | (36 | ) |  | $ | (677 | ) |  | $ | (6 | ) |
| PSE&G |  |  |  |  |  |  |  |  |  |  |
| Assets: |  |  |  |  |  |  |  |  |  |  |
| Rabbi Trust (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 5 |  |  | $ | — |  |  | $ | 5 |  |  | $ | — |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 14 |  |  | $ | — |  |  | $ | — |  |  | $ | 14 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 8 |  |  | $ | — |  |  | $ | — |  |  | $ | 8 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 18 |  |  | $ | — |  |  | $ | — |  |  | $ | 18 |  |  | $ | — |  |
| Power |  |  |  |  |  |  |  |  |  |  |
| Assets: |  |  |  |  |  |  |  |  |  |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | 12 |  |  | $ | (551 | ) |  | $ | 29 |  |  | $ | 527 |  |  | $ | 7 |  |
| NDT Fund (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 900 |  |  | $ | — |  |  | $ | 898 |  |  | $ | 2 |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 171 |  |  | $ | — |  |  | $ | — |  |  | $ | 171 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 320 |  |  | $ | — |  |  | $ | — |  |  | $ | 320 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 487 |  |  | $ | — |  |  | $ | — |  |  | $ | 487 |  |  | $ | — |  |
| Rabbi Trust (C) |  |  |  |  |  |  |  |  |  |  |
| Equity Securities |  | $ | 6 |  |  | $ | — |  |  | $ | 6 |  |  | $ | — |  |  | $ | — |  |
| Debt Securities—U.S. Treasury |  | $ | 17 |  |  | $ | — |  |  | $ | — |  |  | $ | 17 |  |  | $ | — |  |
| Debt Securities—Govt Other |  | $ | 10 |  |  | $ | — |  |  | $ | — |  |  | $ | 10 |  |  | $ | — |  |
| Debt Securities—Corporate |  | $ | 23 |  |  | $ | — |  |  | $ | — |  |  | $ | 23 |  |  | $ | — |  |
| Liabilities: |  |  |  |  |  |  |  |  |  |  |
| Derivative Contracts: |  |  |  |  |  |  |  |  |  |  |
| Energy-Related Contracts (A) |  | $ | (15 | ) |  | $ | 704 |  |  | $ | (36 | ) |  | $ | (677 | ) |  | $ | (6 | ) |

(A) | 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 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
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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.

(B) | Interest rate swaps are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.

(C) | 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 (NAV) 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.

(E) | Represents money market mutual funds.

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’s Risk Management Committee (RMC) approves risk management policies and objectives for risk assessment, control and valuation, counterparty credit approval and the monitoring and reporting of risk exposures. The RMC reports to the Corporate Governance and Audit Committees of the PSEG Board on the scope of the risk management activities and is responsible for approving all valuation procedures at PSEG. Forward price curves for the power market utilized by Power to manage the portfolio are maintained and reviewed by PSEG’s Enterprise Risk Management market pricing group and used for financial reporting purposes. PSEG considers credit and nonperformance 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 nonperformance risk by counterparty. The impacts of credit and nonperformance risk were not material to the financial statements.
The fair value of 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 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
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forward price curves, the fluctuations in fair value have been driven primarily by changes in the observable inputs. The following tables provide details surrounding significant Level 3 valuations as of March 31, 2019 and December 31, 2018.

|  |  | Quantitative Information About Level 3 Fair Value Measurements |  |  |
|  |  |  |  |  |  |  |  | Significant |  |  |
|  |  |  |  | Fair Value as of |  | Valuation |  | Unobservable |  |  |
| Commodity |  | Level 3 Position |  | March 31, 2019 |  | Technique(s) |  | Input |  | Range |
|  |  |  |  | Assets |  | (Liabilities) |  |  |  |  |  |  |
|  |  |  |  | Millions |  |  |  |  |  |  |
| Power |  |  |  |  |  |  |  |  |  |  |  |  |
| Electricity |  | Electric Load Contracts |  | $ | 1 |  |  | $ | (3 | ) |  | Discounted Cash flow |  | Historic Load Variability |  | 0% to 15% |
| Total Power |  |  |  | $ | 1 |  |  | $ | (3 | ) |  |  |  |  |  |  |
| Total PSEG |  |  |  | $ | 1 |  |  | $ | (3 | ) |  |  |  |  |  |  |

|  |  | Quantitative Information About Level 3 Fair Value Measurements |  |  |
|  |  |  |  |  |  |  |  | Significant |  |  |
|  |  |  |  | Fair Value as of |  | Valuation |  | Unobservable |  |  |
| Commodity |  | Level 3 Position |  | December 31, 2018 |  | Technique(s) |  | Input |  | Range |
|  |  |  |  | Assets |  | (Liabilities) |  |  |  |  |  |  |
|  |  |  |  | Millions |  |  |  |  |  |  |
| Power |  |  |  |  |  |  |  |  |  |  |  |  |
| Electricity |  | Electric Load Contracts |  | $ | 2 |  |  | $ | (5 | ) |  | Discounted Cash flow |  | Historic Load Variability |  | 0% to 15% |
| Gas |  | Gas Physical Contracts |  | 5 |  |  | (1 | ) |  | Discounted Cash flow |  | Average Historical Basis |  | -40% to 0% |
| Total Power |  |  |  | $ | 7 |  |  | $ | (6 | ) |  |  |  |  |  |  |
| Total PSEG |  |  |  | $ | 7 |  |  | $ | (6 | ) |  |  |  |  |  |  |

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 Power is a seller, an increase in the load variability would decrease the fair value. For gas-related contracts in cases where Power is a buyer, an increase in the average historical basis would increase the fair value.
A reconciliation of the beginning and ending balances of Level 3 derivative contracts and securities for the three months ended March 31, 2019 and March 31, 2018, respectively, follows:
Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis
for the Three Months Ended March 31, 2019

|  |  | Three Months Ended March 31, 2019 |
| Description |  | Balance as of January 1, 2019 |  | Total Gains or (Losses) Realized/Unrealized Included in Income (A) |  | Purchases (Sales) |  | Issuances/ Settlements (B) |  | Transfers In/Out (C) |  | Balance as of March 31, 2019 |
|  |  | Millions |
| PSEG and Power |  |  |  |  |  |  |  |  |  |  |
| Net Derivative Assets (Liabilities) |  | $ | 1 |  |  | $ | 1 |  |  | $ | — |  |  | $ | (4 | ) |  | $ | — |  |  | $ | (2 | ) |

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Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis
for the Three Months Ended March 31, 2018

|  |  | Three Months Ended March 31, 2018 |
| Description |  | Balance as of January 1, 2018 |  | Total Gains or (Losses) Realized/Unrealized Included in Income (A) |  | Purchases (Sales) |  | Issuances/ Settlements (B) |  | Transfers In/Out (C) |  | Balance as of March 31, 2018 |
|  |  | Millions |
| PSEG and Power |  |  |  |  |  |  |  |  |  |  |
| Net Derivative Assets (Liabilities) |  | $ | 7 |  |  | $ | (1 | ) |  | $ | — |  |  | $ | 1 |  |  | $ | — |  |  | $ | 7 |  |

(A)Unrealized gains (losses) in the following table represent the change in derivative assets and liabilities still held as of March 31, 2019 and 2018.

|  |  | Three Months Ended March 31, |
|  |  | 2019 |  | 2018 |
|  |  | Total Gains (Losses) |  | Unrealized Gains (Losses) |  | Total Gains (Losses) |  | Unrealized Gains (Losses) |
|  |  | Millions |
| PSEG and Power |  |  |  |  |  |  |  |  |
| Operating Revenues |  | $ | 6 |  |  | $ | — |  |  | $ | 8 |  |  | $ | 8 |  |
| Energy Costs |  | (5 | ) |  | (3 | ) |  | (9 | ) |  | (9 | ) |
| Total |  | $ | 1 |  |  | $ | (3 | ) |  | $ | (1 | ) |  | $ | (1 | ) |

(B) | Represents settlements of $(4) million and $1 million for the three months ended March 31, 2019 and 2018.

(C) | There were no transfers into or out of Level 3 during the three months ended March 31, 2019 and 2018.

As of March 31, 2019, PSEG carried $2.3 billion of net assets that are measured at fair value on a recurring basis, of which $2 million of net liabilities was measured using unobservable inputs and classified as Level 3 within the fair value hierarchy.
As of March 31, 2018, PSEG carried $2.4 billion of net assets that are measured at fair value on a recurring basis, of which $7 million of net assets were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy.
Fair Value of Debt
The estimated fair values were determined using the market quotations or values of instruments with similar terms, credit ratings, remaining maturities and redemptions as of March 31, 2019 and December 31, 2018.

|  | As of |  | As of |
|  | March 31, 2019 |  | December 31, 2018 |
|  | Carrying Amount |  | Fair Value |  | Carrying Amount |  | Fair Value |
|  | Millions |
| Long-Term Debt: |  |  |  |  |  |  |  |
| PSEG (A) (B) | $ | 2,094 |  |  | $ | 2,082 |  |  | $ | 2,443 |  |  | $ | 2,397 |  |
| PSE&G (B) | 9,186 |  |  | 9,780 |  |  | 9,184 |  |  | 9,374 |  |
| Power (B) | 2,836 |  |  | 3,069 |  |  | 2,835 |  |  | 2,996 |  |
| Total Long-Term Debt | $ | 14,116 |  |  | $ | 14,931 |  |  | $ | 14,462 |  |  | $ | 14,767 |  |

(A) | As of March 31, 2019 and December 31, 2018, includes floating rate term loans of $700 million and $1,050 million, respectively. The fair values of the term loan debt (Level 2 measurement) approximate the carrying value because the interest payments are based on LIBOR rates that are reset monthly and the debt is redeemable at face value by PSEG at any time.

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(B) | 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 and utilizes assumptions of current market pricing curves. In order to incorporate the credit risk into the discount rates, pricing (i.e. U.S. Treasury rate plus credit spread) is based on expected new issue pricing across each of the companies’ respective debt maturity spectrum. The credit spreads of various tenors obtained from this information are added to the appropriate benchmark U.S. Treasury rates in order to determine the current market yields for the various tenors. The yields are then converted into discount rates of various tenors that are used for discounting the respective cash flows of the same tenor for each bond or note. 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.

Note 15. Other Income (Deductions)

|  | PSE&G |  | Power |  | Other (A) |  | Consolidated |
|  | Millions |
| Three Months Ended March 31, 2019 |  |  |  |  |  |  |  |
| NDT Fund Interest and Dividends | $ | — |  |  | $ | 14 |  |  | $ | — |  |  | $ | 14 |  |
| Allowance for Funds Used During Construction | 13 |  |  | — |  |  | — |  |  | 13 |  |
| Solar Loan Interest | 4 |  |  | — |  |  | — |  |  | 4 |  |
| Other | 2 |  |  | (1 | ) |  | 1 |  |  | 2 |  |
| Total Other Income (Deductions) | $ | 19 |  |  | $ | 13 |  |  | $ | 1 |  |  | $ | 33 |  |
| Three Months Ended March 31, 2018 |  |  |  |  |  |  |  |
| NDT Fund Interest and Dividends | $ | — |  |  | $ | 12 |  |  | $ | — |  |  | $ | 12 |  |
| Allowance for Funds Used During Construction | 14 |  |  | — |  |  | — |  |  | 14 |  |
| Solar Loan Interest | 4 |  |  | — |  |  | — |  |  | 4 |  |
| Other | 2 |  |  | (1 | ) |  | 1 |  |  | 2 |  |
| Total Other Income (Deductions) | $ | 20 |  |  | $ | 11 |  |  | $ | 1 |  |  | $ | 32 |  |

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

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Note 16. Income Taxes
PSEG’s, PSE&G’s and Power’s effective tax rates for the three months ended March 31, 2019 and 2018 were as follows:

|  | Three Months Ended |
|  | March 31, |
|  | 2019 |  | 2018 |
| PSEG | 17.6% |  | 26.6% |
| PSE&G | 5.8% |  | 26.8% |
| Power | 29.5% |  | 26.2% |

For the three months ended March 31, 2019, the difference in PSEG’s effective tax rate as compared to the same period in the prior year and the statutory tax rate of 28.11% was due primarily to the flow-back of PSE&G’s excess deferred income tax liabilities as a result of the Tax Act and tax repair-related accumulated deferred income taxes as a result of PSE&G’s 2018 settled distribution base rate case and the FERC approved Section 205 filing, where applicable.
For the three months ended March 31, 2019, the difference in PSE&G’s effective tax rate as compared to the same period in the prior year and the statutory tax rate of 28.11% was due primarily to the flow-back of PSE&G’s excess deferred income tax liabilities as a result of the Tax Act and tax repair-related accumulated deferred income taxes as a result of PSE&G’s 2018 settled distribution base rate case and the FERC approved Section 205 filing, where applicable.
For the three months ended March 31, 2019, the difference in Power’s effective tax rate as compared to the same period in the prior year and the statutory tax rate of 28.11%was due primarily to higher pre-tax income from the NDT qualified fund in 2019, which is subject to an additional trust tax.
Tax Act
Effective January 1, 2018, the U.S. federal corporate tax rate was reduced from a maximum of 35% to 21% resulting in a decrease in PSEG’s, PSE&G’s and Power’s effective income tax rates. To the extent allowed under the Tax Act, Power’s operating cash flows reflect the full expensing of capital investments for income tax purposes. The Tax Act has led to lower customer rates due to lower income tax expense recoveries and the BPU and FERC have approved PSEG’s proposals to refund excess deferred income tax Regulatory Liabilities. The impact of the lower federal income tax rate on PSE&G was reflected in PSE&G’s distribution base rate proceeding and its 2018 transmission formula rate filings. The Tax Act is generally expected to result in lower operating cash flows for PSE&G resulting from the elimination of bonus depreciation, partially offset by higher revenues due to the higher rate base.
In August 2018, the IRS issued a Notice of Proposed Rulemaking (Notice) regarding the application of tax depreciation rules as amended by the Tax Act. While the Notice provides some guidance as to the application of the changes made by the Tax Act to the bonus depreciation rules, certain aspects still remain unclear. Further, in November 2018 the IRS issued Proposed Regulations addressing the interest disallowance rules contained in the Tax Act. For non-regulated businesses, these rules set a cap on the amount of interest that can be deducted in a given year. Any amount that is disallowed can be carried forward indefinitely. For 2019, PSEG and Power expect that a portion of the interest will be disallowed in the current period but realized in future periods. However, certain aspects of the proposed regulations are unclear. Therefore, PSEG recorded taxes based on its interpretation of the relevant statutes.
Depreciation amounts recorded in 2019 were based on PSEG’s interpretation of the Tax Act and the depreciation rules contained in the Notice. Such amounts are subject to change based on several factors, including but not limited to, the IRS and state taxing authorities issuing final guidance and/or further clarification. Any further guidance or clarification could impact PSEG’s, PSE&G’s and Power’s financial statements.
New Jersey State Tax Reform
In 2018, the State of New Jersey made significant changes to its income tax laws, including imposing a temporary surtax of 2.5% effective January 1, 2018 and 2019 and 1.5% in 2020 and 2021, as well as requiring corporate taxpayers to file in a combined reporting group as defined under New Jersey law starting in 2019. Both provisions include an exemption for public utilities. At this time, PSEG believes PSE&G meets the definition of a public utility and, therefore, will not be impacted by the temporary surtax or be included in the combined reporting group.
In 2019, the State of New Jersey issued further guidance regarding the temporary surtax and clarified that New Jersey net operating loss carryovers can be deducted in computing a taxpayer’s entire net income.
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Note 17. Accumulated Other Comprehensive Income (Loss), Net of Tax

| PSEG |  | Other Comprehensive Income (Loss) |
|  |  | Three Months Ended March 31, 2019 |
| Accumulated Other Comprehensive Income (Loss) |  | Cash Flow Hedges |  | Pension and OPEB Plans |  | Available-for-Sale Securities |  | Total |
|  |  | Millions |
| Balance as of December 31, 2018 |  | $ | (1 | ) |  | $ | (360 | ) |  | $ | (16 | ) |  | $ | (377 | ) |
| Cumulative Effect Adjustment to Reclassify Stranded Tax Effects Resulting from the Change in the Federal Corporate Income Tax Rate to Retained Earnings |  | — |  |  | (81 | ) |  | — |  |  | (81 | ) |
| Current Period Other Comprehensive Income (Loss) |  |  |  |  |  |  |  |  |
| Other Comprehensive Income before Reclassifications |  | (4 | ) |  | (3 | ) |  | 20 |  |  | 13 |  |
| Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | — |  |  | 3 |  |  | 1 |  |  | 4 |  |
| Net Current Period Other Comprehensive Income (Loss) |  | (4 | ) |  | — |  |  | 21 |  |  | 17 |  |
| Net Change in Accumulated Other Comprehensive Income (Loss) |  | (4 | ) |  | (81 | ) |  | 21 |  |  | (64 | ) |
| Balance as of March 31, 2019 |  | $ | (5 | ) |  | $ | (441 | ) |  | $ | 5 |  |  | $ | (441 | ) |
| PSEG |  | Other Comprehensive Income (Loss) |
|  |  | Three Months Ended March 31, 2018 |
| Accumulated Other Comprehensive Income (Loss) |  | Cash Flow Hedges |  | Pension and OPEB Plans |  | Available-for-Sale Securities |  | Total |
|  |  | Millions |
| Balance as of December 31, 2017 |  | $ | — |  |  | $ | (406 | ) |  | $ | 177 |  |  | $ | (229 | ) |
| Cumulative Effect Adjustment to Reclassify Unrealized Net Gains on Equity Investments to Retained Earnings |  | — |  |  | — |  |  | (176 | ) |  | (176 | ) |
| Current Period Other Comprehensive Income (Loss) |  |  |  |  |  |  |  |  |
| Other Comprehensive Income before Reclassifications |  | — |  |  | — |  |  | (16 | ) |  | (16 | ) |
| Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | — |  |  | 8 |  |  | 2 |  |  | 10 |  |
| Net Current Period Other Comprehensive Income (Loss) |  | — |  |  | 8 |  |  | (14 | ) |  | (6 | ) |
| Net Change in Accumulated Other Comprehensive Income (Loss) |  | — |  |  | 8 |  |  | (190 | ) |  | (182 | ) |
| Balance as of March 31, 2018 |  | $ | — |  |  | $ | (398 | ) |  | $ | (13 | ) |  | $ | (411 | ) |

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| Power |  | Other Comprehensive Income (Loss) |
|  |  | Three Months Ended March 31, 2019 |
| Accumulated Other Comprehensive Income (Loss) |  | Cash Flow Hedges |  | Pension and OPEB Plans |  | Available-for-Sale Securities |  | Total |
|  |  | Millions |
| Balance as of December 31, 2018 |  | $ | — |  |  | $ | (306 | ) |  | $ | (13 | ) |  | $ | (319 | ) |
| Cumulative Effect Adjustment to Reclassify Stranded Tax Effects Resulting from the Change in the Federal Corporate Income Tax Rate to Retained Earnings |  | — |  |  | (69 | ) |  | — |  |  | (69 | ) |
| Current Period Other Comprehensive Income (Loss) |  |  |  |  |  |  |  |  |
| Other Comprehensive Income before Reclassifications |  | — |  |  | (3 | ) |  | 15 |  |  | 12 |  |
| Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | — |  |  | 3 |  |  | 1 |  |  | 4 |  |
| Net Current Period Other Comprehensive Income (Loss) |  | — |  |  | — |  |  | 16 |  |  | 16 |  |
| Net Change in Accumulated Other Comprehensive Income (Loss) |  | — |  |  | (69 | ) |  | 16 |  |  | (53 | ) |
| Balance as of March 31, 2019 |  | $ | — |  |  | $ | (375 | ) |  | $ | 3 |  |  | $ | (372 | ) |
| Power |  | Other Comprehensive Income (Loss) |
|  |  | Three Months Ended March 31, 2018 |
| Accumulated Other Comprehensive Income (Loss) |  | Cash Flow Hedges |  | Pension and OPEB Plans |  | Available-for-Sale Securities |  | Total |
|  |  | Millions |
| Balance as of December 31, 2017 |  | $ | — |  |  | $ | (347 | ) |  | $ | 175 |  |  | $ | (172 | ) |
| Cumulative Effect Adjustment to Reclassify Unrealized Net Gains on Equity Investments to Retained Earnings |  | — |  |  | — |  |  | (175 | ) |  | (175 | ) |
| Current Period Other Comprehensive Income (Loss) |  |  |  |  |  |  |  |  |
| Other Comprehensive Income before Reclassifications |  | — |  |  | — |  |  | (13 | ) |  | (13 | ) |
| Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | — |  |  | 6 |  |  | 2 |  |  | 8 |  |
| Net Current Period Other Comprehensive Income (Loss) |  | — |  |  | 6 |  |  | (11 | ) |  | (5 | ) |
| Net Change in Accumulated Other Comprehensive Income (Loss) |  | — |  |  | 6 |  |  | (186 | ) |  | (180 | ) |
| Balance as of March 31, 2018 |  | $ | — |  |  | $ | (341 | ) |  | $ | (11 | ) |  | $ | (352 | ) |

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| PSEG |  |  | Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement |
|  |  |  | Three Months Ended |
| Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | Location of Pre-Tax Amount In Statement of Operations | March 31, 2019 |
|  | 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) | $ | 7 |  |  | $ | (2 | ) |  | $ | 5 |  |
| Amortization of Actuarial Loss |  | Non-Operating Pension and OPEB Credits (Costs) | (12 | ) |  | 4 |  |  | (8 | ) |
| Total Pension and OPEB Plans | (5 | ) |  | 2 |  |  | (3 | ) |
| Available-for-Sale Debt Securities |  |  |  |  |  |
| Realized Gains (Losses) |  | Net Gains (Losses) on Trust Investments | (1 | ) |  | — |  |  | (1 | ) |
| Total Available-for-Sale Debt Securities | (1 | ) |  | — |  |  | (1 | ) |
| Total |  |  | $ | (6 | ) |  | $ | 2 |  |  | $ | (4 | ) |

| PSEG |  |  | Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement |
|  |  |  | Three Months Ended |
| Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | Location of Pre-Tax Amount In Statement of Operations | March 31, 2018 |
|  | 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) | $ | 1 |  |  | $ | — |  |  | $ | 1 |  |
| Amortization of Actuarial Loss |  | Non-Operating Pension and OPEB Credits (Costs) | (12 | ) |  | 3 |  |  | (9 | ) |
| Total Pension and OPEB Plans | (11 | ) |  | 3 |  |  | (8 | ) |
| Available-for-Sale Debt Securities |  |  |  |  |  |
| Realized Gains (Losses) |  | Net Gains (Losses) on Trust Investments | (4 | ) |  | 2 |  |  | (2 | ) |
| Total Available-for-Sale Debt Securities | (4 | ) |  | 2 |  |  | (2 | ) |
| Total |  |  | $ | (15 | ) |  | $ | 5 |  |  | $ | (10 | ) |

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| Power |  |  | Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement |
|  |  |  | Three Months Ended |
| Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | Location of Pre-Tax Amount In Statement of Operations | March 31, 2019 |
|  | 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 |  |
| Amortization of Actuarial Loss |  | Non-Operating Pension and OPEB Credits (Costs) | (10 | ) |  | 3 |  |  | (7 | ) |
| Total Pension and OPEB Plans | (4 | ) |  | 1 |  |  | (3 | ) |
| Available-for-Sale Debt Securities |  |  |  |  |  |
| Realized Gains (Losses) |  | Net Gains (Losses) on Trust Investments | (1 | ) |  | — |  |  | (1 | ) |
| Total Available-for-Sale Debt Securities | (1 | ) |  | — |  |  | (1 | ) |
| Total |  |  | $ | (5 | ) |  | $ | 1 |  |  | $ | (4 | ) |

| Power |  |  | Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement |
|  |  |  | Three Months Ended |
| Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) |  | Location of Pre-Tax Amount In Statement of Operations | March 31, 2018 |
|  | 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) | $ | 1 |  |  | $ | — |  |  | $ | 1 |  |
| Amortization of Actuarial Loss |  | Non-Operating Pension and OPEB Credits (Costs) | (10 | ) |  | 3 |  |  | (7 | ) |
| Total Pension and OPEB Plans | (9 | ) |  | 3 |  |  | (6 | ) |
| Available-for-Sale Debt Securities |  |  |  |  |  |
| Realized Gains (Losses) |  | Net Gains (Losses) on Trust Investments | (4 | ) |  | 2 |  |  | (2 | ) |
| Total Available-for-Sale Debt Securities | (4 | ) |  | 2 |  |  | (2 | ) |
| Total |  |  | $ | (13 | ) |  | $ | 5 |  |  | $ | (8 | ) |

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Note 18. Earnings Per Share (EPS) and Dividends
EPS
Diluted EPS is calculated by dividing Net Income by the weighted average number of shares of common stock outstanding, including shares issuable upon exercise of stock options outstanding or vesting of restricted stock awards granted under PSEG’s stock compensation plans and upon payment of performance units or restricted stock units. The following table shows the effect of these stock options, performance units and restricted stock units on the weighted average number of shares outstanding used in calculating diluted EPS:

|  | Three Months Ended March 31, |
|  | 2019 |  | 2018 |
|  | Basic |  | Diluted |  | Basic |  | Diluted |
| EPS Numerator (Millions): |  |  |  |  |  |  |  |
| Net Income | $ | 700 |  |  | $ | 700 |  |  | $ | 558 |  |  | $ | 558 |  |
| EPS Denominator (Millions): |  |  |  |  |  |  |  |
| Weighted Average Common Shares Outstanding | 504 |  |  | 504 |  |  | 504 |  |  | 504 |  |
| Effect of Stock Based Compensation Awards | — |  |  | 3 |  |  | — |  |  | 3 |  |
| Total Shares | 504 |  |  | 507 |  |  | 504 |  |  | 507 |  |
| EPS |  |  |  |  |  |  |  |
| Net Income | $ | 1.39 |  |  | $ | 1.38 |  |  | $ | 1.11 |  |  | $ | 1.10 |  |

Dividends

|  | Three Months Ended |
|  | March 31, |
| Dividend Payments on Common Stock | 2019 |  | 2018 |
| Per Share | $ | 0.47 |  |  | $ | 0.45 |  |
| In Millions | $ | 238 |  |  | $ | 227 |  |

On April 16, 2019, the PSEG Board approved a $0.47 per share common stock dividend for the second quarter of 2019.
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Note 19. Financial Information by Business Segment

|  | PSE&G |  | Power |  | Other (A) |  | Eliminations (B) |  | Consolidated Total |
|  | Millions |
| Three Months Ended March 31, 2019 |  |  |  |  |  |  |  |  |  |
| Operating Revenues | $ | 2,032 |  |  | $ | 1,416 |  |  | $ | 141 |  |  | $ | (609 | ) |  | $ | 2,980 |  |
| Net Income (Loss) | 403 |  |  | 296 |  |  | 1 |  |  | — |  |  | 700 |  |
| Gross Additions to Long-Lived Assets | 625 |  |  | 167 |  |  | 3 |  |  | — |  |  | 795 |  |
| Three Months Ended March 31, 2018 |  |  |  |  |  |  |  |  |  |
| Operating Revenues | $ | 1,845 |  |  | $ | 1,403 |  |  | $ | 147 |  |  | $ | (577 | ) |  | $ | 2,818 |  |
| Net Income (Loss) | 319 |  |  | 234 |  |  | 5 |  |  | — |  |  | 558 |  |
| Gross Additions to Long-Lived Assets | 750 |  |  | 299 |  |  | 4 |  |  | — |  |  | 1,053 |  |
| As of March 31, 2019 |  |  |  |  |  |  |  |  |  |
| Total Assets | $ | 31,500 |  |  | $ | 12,671 |  |  | $ | 2,333 |  |  | $ | (748 | ) |  | $ | 45,756 |  |
| Investments in Equity Method Subsidiaries | $ | — |  |  | $ | 86 |  |  | $ | — |  |  | $ | — |  |  | $ | 86 |  |
| As of December 31, 2018 |  |  |  |  |  |  |  |  |  |
| Total Assets | $ | 31,109 |  |  | $ | 12,594 |  |  | $ | 2,604 |  |  | $ | (981 | ) |  | $ | 45,326 |  |
| Investments in Equity Method Subsidiaries | $ | — |  |  | $ | 86 |  |  | $ | — |  |  | $ | — |  |  | $ | 86 |  |

(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 corporation) and Services.

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

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 |
|  | March 31, |
| Related-Party Transactions | 2019 |  | 2018 |
|  | Millions |
| Billings from Affiliates: |  |  |  |
| Net Billings from Power primarily through BGS and BGSS (A) | $ | 633 |  |  | $ | 578 |  |
| Administrative Billings from Services (B) | 75 |  |  | 83 |  |
| Total Billings from Affiliates | $ | 708 |  |  | $ | 661 |  |

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|  | As of |  | As of |
| Related-Party Transactions | March 31, 2019 |  | December 31, 2018 |
|  | Millions |
| Receivables from PSEG (C) | $ | — |  |  | $ | 123 |  |
| Payable to Power (A) | $ | 207 |  |  | $ | 245 |  |
| Payable to Services (B) | 62 |  |  | 76 |  |
| Payables to PSEG (C) | 5 |  |  | — |  |
| Accounts Payable—Affiliated Companies | $ | 274 |  |  | $ | 321 |  |
| Working Capital Advances to Services (D) | $ | 33 |  |  | $ | 33 |  |
| Long-Term Accrued Taxes Payable | $ | 69 |  |  | $ | 69 |  |

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

|  | Three Months Ended |
|  | March 31, |
| Related-Party Transactions | 2019 |  | 2018 |
|  | Millions |
| Billings to Affiliates: |  |  |  |
| Net Billings to PSE&G primarily through BGS and BGSS (A) | $ | 633 |  |  | $ | 578 |  |
| Billings from Affiliates: |  |  |  |
| Administrative Billings from Services (B) | $ | 45 |  |  | $ | 43 |  |

|  | As of |  | As of |
| Related-Party Transactions | March 31, 2019 |  | December 31, 2018 |
|  | Millions |
| Receivable from PSE&G (A) | $ | 207 |  |  | $ | 245 |  |
| Receivables from PSEG (C) | 77 |  |  | 29 |  |
| Accounts Receivable—Affiliated Companies | $ | 284 |  |  | $ | 274 |  |
| Payable to Services (B) | $ | 21 |  |  | $ | 16 |  |
| Accounts Payable—Affiliated Companies | $ | 21 |  |  | $ | 16 |  |
| Short-Term Loan to (from) Affiliate (E) | $ | 87 |  |  | $ | (193 | ) |
| Working Capital Advances to Services (D) | $ | 17 |  |  | $ | 17 |  |
| Long-Term Accrued Taxes Payable | $ | 82 |  |  | $ | 76 |  |

(A) | PSE&G has entered into a requirements contract with Power under which Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process. The rates in the BGS and BGSS contracts are prescribed by the BPU. In addition, 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 Power at cost. In addition, PSE&G and Power have other payables to Services, including amounts related to certain common costs, such as pension and OPEB 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 net operating losses 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 Power have advanced working capital to Services. The amounts are included in Other Noncurrent Assets on PSE&G’s and Power’s Condensed Consolidated Balance Sheets.

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(E) | 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.

Note 21. Guarantees of Debt
Power’s Senior Notes are fully and unconditionally and jointly and severally guaranteed by its subsidiaries, PSEG Fossil LLC, PSEG Nuclear LLC and PSEG Energy Resources & Trade LLC. The following tables present condensed financial information for the guarantor subsidiaries, as well as Power’s non-guarantor subsidiaries, as of March 31, 2019 and December 31, 2018 and for the three months ended March 31, 2019 and 2018.

|  | Power |  | Guarantor Subsidiaries |  | Other Subsidiaries |  | Consolidating Adjustments |  | Total |
|  | Millions |
| Three Months Ended March 31, 2019 |  |  |  |  |  |  |  |  |  |
| Operating Revenues | $ | — |  |  | $ | 1,401 |  |  | $ | 56 |  |  | $ | (41 | ) |  | $ | 1,416 |  |
| Operating Expenses | 1 |  |  | 1,094 |  |  | 61 |  |  | (41 | ) |  | 1,115 |  |
| Operating Income (Loss) | (1 | ) |  | 307 |  |  | (5 | ) |  | — |  |  | 301 |  |
| Equity Earnings (Losses) of Subsidiaries | 309 |  |  | (8 | ) |  | 2 |  |  | (301 | ) |  | 2 |  |
| Net Gains (Losses) on Trust Investments | 1 |  |  | 125 |  |  | — |  |  | — |  |  | 126 |  |
| Other Income (Deductions) | 47 |  |  | 55 |  |  | — |  |  | (89 | ) |  | 13 |  |
| Non-Operating Pension and OPEB Credits (Costs) | — |  |  | 3 |  |  | — |  |  | — |  |  | 3 |  |
| Interest Expense | (75 | ) |  | (31 | ) |  | (8 | ) |  | 89 |  |  | (25 | ) |
| Income Tax Benefit (Expense) | 15 |  |  | (144 | ) |  | 5 |  |  | — |  |  | (124 | ) |
| Net Income (Loss) | $ | 296 |  |  | $ | 307 |  |  | $ | (6 | ) |  | $ | (301 | ) |  | $ | 296 |  |
| Comprehensive Income (Loss) | $ | 312 |  |  | $ | 322 |  |  | $ | (6 | ) |  | $ | (316 | ) |  | $ | 312 |  |
| Three Months Ended March 31, 2019 |  |  |  |  |  |  |  |  |  |
| Net Cash Provided By (Used In) Operating Activities | $ | (22 | ) |  | $ | 799 |  |  | $ | 43 |  |  | $ | (94 | ) |  | $ | 726 |  |
| Net Cash Provided By (Used In) Investing Activities | $ | (167 | ) |  | $ | (713 | ) |  | $ | (124 | ) |  | $ | 728 |  |  | $ | (276 | ) |
| Net Cash Provided By (Used In) Financing Activities | $ | 189 |  |  | $ | (86 | ) |  | $ | 87 |  |  | $ | (634 | ) |  | $ | (444 | ) |

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|  | Power |  | Guarantor Subsidiaries |  | Other Subsidiaries |  | Consolidating Adjustments |  | Total |
|  | Millions |
| Three Months Ended March 31, 2018 |  |  |  |  |  |  |  |  |  |
| Operating Revenues | $ | — |  |  | $ | 1,386 |  |  | $ | 51 |  |  | $ | (34 | ) |  | $ | 1,403 |  |
| Operating Expenses | — |  |  | 1,056 |  |  | 52 |  |  | (34 | ) |  | 1,074 |  |
| Operating Income (Loss) | — |  |  | 330 |  |  | (1 | ) |  | — |  |  | 329 |  |
| Equity Earnings (Losses) of Subsidiaries | 234 |  |  | (3 | ) |  | 2 |  |  | (231 | ) |  | 2 |  |
| Net Gains (Losses) on Trust Investments | — |  |  | (22 | ) |  | — |  |  | — |  |  | (22 | ) |
| Other Income (Deductions) | 35 |  |  | 33 |  |  | — |  |  | (57 | ) |  | 11 |  |
| Non-Operating Pension and OPEB Credits (Costs) | — |  |  | 4 |  |  | — |  |  | — |  |  | 4 |  |
| Interest Expense | (42 | ) |  | (17 | ) |  | (5 | ) |  | 57 |  |  | (7 | ) |
| Income Tax Benefit (Expense) | 7 |  |  | (92 | ) |  | 2 |  |  | — |  |  | (83 | ) |
| Net Income (Loss) | $ | 234 |  |  | $ | 233 |  |  | $ | (2 | ) |  | $ | (231 | ) |  | $ | 234 |  |
| Comprehensive Income (Loss) | $ | 229 |  |  | $ | 223 |  |  | $ | (2 | ) |  | $ | (221 | ) |  | $ | 229 |  |
| Three Months Ended March 31, 2018 |  |  |  |  |  |  |  |  |  |
| Net Cash Provided By (Used In) Operating Activities | $ | (5 | ) |  | $ | 525 |  |  | $ | (49 | ) |  | $ | 71 |  |  | $ | 542 |  |
| Net Cash Provided By (Used In) Investing Activities | $ | (215 | ) |  | $ | (625 | ) |  | $ | (82 | ) |  | $ | 605 |  |  | $ | (317 | ) |
| Net Cash Provided By (Used In) Financing Activities | $ | 220 |  |  | $ | 100 |  |  | $ | 111 |  |  | $ | (677 | ) |  | $ | (246 | ) |

|  | Power |  | Guarantor Subsidiaries |  | Other Subsidiaries |  | Consolidating Adjustments |  | Total |
|  | Millions |
| As of March 31, 2019 |  |  |  |  |  |  |  |  |  |
| Current Assets | $ | 4,518 |  |  | $ | 1,693 |  |  | $ | 318 |  |  | $ | (5,217 | ) |  | $ | 1,312 |  |
| Property, Plant and Equipment, net | 48 |  |  | 4,915 |  |  | 3,913 |  |  | — |  |  | 8,876 |  |
| Investment in Subsidiaries | 5,309 |  |  | 1,099 |  |  | — |  |  | (6,408 | ) |  | — |  |
| Noncurrent Assets | 278 |  |  | 2,277 |  |  | 137 |  |  | (209 | ) |  | 2,483 |  |
| Total Assets | $ | 10,153 |  |  | $ | 9,984 |  |  | $ | 4,368 |  |  | $ | (11,834 | ) |  | $ | 12,671 |  |
| Current Liabilities | $ | 776 |  |  | $ | 2,966 |  |  | $ | 2,113 |  |  | $ | (5,217 | ) |  | $ | 638 |  |
| Noncurrent Liabilities | 519 |  |  | 2,072 |  |  | 793 |  |  | (209 | ) |  | 3,175 |  |
| Long-Term Debt | 2,836 |  |  | — |  |  | — |  |  | — |  |  | 2,836 |  |
| Member’s Equity | 6,022 |  |  | 4,946 |  |  | 1,462 |  |  | (6,408 | ) |  | 6,022 |  |
| Total Liabilities and Member’s Equity | $ | 10,153 |  |  | $ | 9,984 |  |  | $ | 4,368 |  |  | $ | (11,834 | ) |  | $ | 12,671 |  |
| As of December 31, 2018 |  |  |  |  |  |  |  |  |  |
| Current Assets | $ | 4,317 |  |  | $ | 1,479 |  |  | $ | 304 |  |  | $ | (4,593 | ) |  | $ | 1,507 |  |
| Property, Plant and Equipment, net | 49 |  |  | 4,971 |  |  | 3,822 |  |  | — |  |  | 8,842 |  |
| Investment in Subsidiaries | 5,062 |  |  | 1,107 |  |  | — |  |  | (6,169 | ) |  | — |  |
| Noncurrent Assets | 273 |  |  | 2,109 |  |  | 101 |  |  | (238 | ) |  | 2,245 |  |
| Total Assets | $ | 9,701 |  |  | $ | 9,666 |  |  | $ | 4,227 |  |  | $ | (11,000 | ) |  | $ | 12,594 |  |
| Current Liabilities | $ | 437 |  |  | $ | 2,971 |  |  | $ | 2,027 |  |  | $ | (4,593 | ) |  | $ | 842 |  |
| Noncurrent Liabilities | 513 |  |  | 1,996 |  |  | 730 |  |  | (238 | ) |  | 3,001 |  |
| Long-Term Debt | 2,791 |  |  | — |  |  | — |  |  | — |  |  | 2,791 |  |
| Member’s Equity | 5,960 |  |  | 4,699 |  |  | 1,470 |  |  | (6,169 | ) |  | 5,960 |  |
| Total Liabilities and Member’s Equity | $ | 9,701 |  |  | $ | 9,666 |  |  | $ | 4,227 |  |  | $ | (11,000 | ) |  | $ | 12,594 |  |

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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 (Power). Information contained herein relating to any individual company is filed by such company on its own behalf. PSE&G and 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

• | 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. In addition, Power owns and operates solar generation in various states. 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 Operations Services Agreement; PSEG Energy Holdings L.L.C. (Energy Holdings), which primarily has investments in leveraged leases; 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 2018 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 2018 and Future Outlook provided in Item 7 in our Form 10-K by describing significant events and business developments that have occurred during 2019 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 2019 AND FUTURE OUTLOOK
Our business plan is designed to achieve growth while managing the risks associated with fluctuating commodity prices and changes in customer demand.
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. Over the past few years, our investments have altered our business mix to reflect a higher percentage of earnings contribution by PSE&G. Over the next five years, we expect to invest between $11 billion and $16 billion in our business which is expected to provide an annual rate base growth of 7%—9%.
In May 2018, we received approval for our Gas System Modernization Program II (GSMP II), an expanded, five-year program to invest $1.9 billion beginning in 2019 to replace approximately 875 miles of cast iron and unprotected steel mains in addition to other improvements to the gas system. Approximately $1.6 billion will be recovered through periodic rate roll-ins, with the remaining $300 million to be recovered through a future base rate proceeding. As part of the settlement, PSE&G agreed to file a base rate proceeding no later than five years from the commencement of the program, to maintain a base level of gas distribution capital expenditures of $155 million per year and to achieve certain leak reduction targets.
In June 2018, we filed for our Energy Strong Program II (ES II), a proposed five-year $2.5 billion program to harden, modernize and make our electric and gas distribution systems more resilient. The size and duration of ES II, as well as certain other elements of the program, are subject to BPU approval. The review process is expected to conclude in the third quarter of 2019.
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In October 2018, we filed our proposed Clean Energy Future (CEF) program with the BPU, a six-year estimated $3.5 billion investment covering four programs; (i) an Energy Efficiency (EE) program totaling $2.5 billion of investment designed to achieve energy efficiency targets required under New Jersey’s Clean Energy law; (ii) an Electric Vehicle (EV) infrastructure program; (iii) an Energy Storage (ES) program and (iv) an Energy Cloud (EC) program which will include installing approximately two million electric smart meters and associated infrastructure. The review process for the CEF-EE program is expected to conclude by the third quarter of 2019. The CEF-EV/ES and CEF-EC programs will have separate procedural schedules.
In November 2018, the New Jersey Division of Rate Counsel (Rate Counsel) filed a motion to dismiss the CEF-EC filing on the basis that the BPU announced a moratorium on electric distribution companies’ advanced meter infrastructure programs. In December 2018, Rate Counsel filed a motion to stay the CEF-EV/ES filing, arguing that the BPU should conclude other regulatory proceedings addressing EVs and ES, including the new Energy Master Plan and initiatives required by the Clean Energy Act, before it rules on PSE&G’s program. We opposed Rate Counsel’s motions, asking for the BPU to permit these filings to proceed. There is no timetable for the BPU to decide on Rate Counsel’s motions.
We also continue to invest in transmission infrastructure in order to (i) maintain and enhance system integrity and grid reliability, grid security and safety, (ii) address an aging transmission infrastructure, (iii) leverage technology to improve the operation of the system, (iv) reduce transmission constraints, (v) meet growing demand and (vi) meet environmental requirements and standards set by various regulatory bodies. Our planned capital spending for transmission in 2019-2021 is $3.4 billion.
Power
At Power, we strive to improve performance and reduce 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. Power continues to move its fleet toward improved efficiency and believes that its investment program enhances its competitive position with the addition of efficient, clean, reliable combined cycle gas turbine capacity. 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. Power’s hedging practices and ability to capitalize on market opportunities help it to balance some of the volatility of the merchant power business. More than half of Power’s expected gross margin in 2019 relates to our hedging strategy, our expected revenues from the capacity market mechanisms and certain ancillary service payments such as reactive power.
In mid-2018, we commenced commercial operations of Keys Energy Center (Keys) and Sewaren 7. Construction continues on Bridgeport Harbor Station Unit 5 (BH5), which is targeted for commercial operation in mid-2019. Our investments in these units reflect our recognition of the value of opportunistic growth in the Power business. These additions to our fleet both expand our geographic diversity and adjust our fuel mix and enhance the environmental profile and overall efficiency of Power’s generation fleet.
Operational Excellence
We emphasize operational performance while developing opportunities in both our competitive and regulated businesses. Flexibility in our generating fleet has allowed us to take advantage of opportunities in a rapidly evolving market as we remain diligent in managing costs. In the first three months of 2019, our

• | utility continued its efforts to control costs while maintaining strong operational performance,

• | diverse fuel mix and dispatch flexibility allowed us to generate approximately 14 terawatt hours while addressing fuel availability and price volatility, and

• | total nuclear fleet achieved a capacity factor of 98.0%.

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 three months of 2019 as we

• | maintained sufficient liquidity,

• | maintained solid investment grade credit ratings, and

• | increased our indicative annual dividend for 2019 to $1.88 per share.

We expect to be able to fund our planned capital requirements, as described in Liquidity and Capital Resources, and the impacts of the Tax Cuts and Jobs Act of 2017 (Tax Act) without the issuance of new equity. For additional information on the impacts of
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the Tax Act, see Tax Legislation below.
Financial Results
As a result of the settlement of PSE&G’s distribution base rate proceeding in October 2018, with new rates effective November 1, 2018, PSE&G expects a net reduction in overall annual revenues of approximately $13 million. This is comprised of a $212 million increase in base revenues, including recovery of deferred storm costs, offset by the return of tax benefits of approximately $225 million. The tax benefits include the flow-back to customers of excess accumulated deferred income taxes resulting from the reduction of the federal income tax rates provided in the Tax Act as well as the accumulated deferred income taxes from previously realized tax repair deductions and tax benefits from future tax repair deductions as realized.
PSE&G also filed a revised 2019 Annual Transmission Formula Rate Update to include the refund of the approved excess deferred income tax benefits. The revised 2019 Annual Transmission Formula Rate, as filed with FERC in January 2019, decreases overall annual transmission revenues by approximately $54 million, subject to true-up.
The results for PSEG, PSE&G and Power for the three months ended March 31, 2019 and 2018 are presented as follows:

|  | Three Months Ended |
|  | March 31, |
| Earnings (Losses) | 2019 |  | 2018 |
|  | Millions |
| PSE&G | $ | 403 |  |  | $ | 319 |  |
| Power | 296 |  |  | 234 |  |
| Other (A) | 1 |  |  | 5 |  |
| PSEG Net Income | $ | 700 |  |  | $ | 558 |  |
| PSEG Net Income Per Share (Diluted) | $ | 1.38 |  |  | $ | 1.10 |  |

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

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 |
|  | March 31, |
|  | 2019 |  | 2018 |
|  | Millions, after tax |
| NDT Fund Income (Expense) (A) (B) | $ | 76 |  |  | $ | (16 | ) |
| Non-Trading MTM Gains (Losses) (C) | $ | 76 |  |  | $ | 85 |  |

(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 (Deductions), interest accretion expense on 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 $(51) million and $8 million for the three months ended March 31, 2019 and 2018, respectively.

(C) | Net of tax expense of $(30) million and $(33) million for the three months ended March 31, 2019 and 2018, respectively.

Our $142 million increase in Net Income for the three months ended March 31, 2019 was driven largely by

• | net unrealized gains in 2019 as compared to net unrealized losses in 2018 on equity securities in the NDT Fund at Power, and

• | higher earnings due to investments in T&D programs and the favorable impact of new rates effective November 1, 2018 as a result of the BPU approval of our distribution base rate proceeding at PSE&G.

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The greater emphasis on capital spending in recent years for projects on which we receive contemporaneous returns at PSE&G has yielded strong results, which when combined with the cash flow generated by Power, has allowed us to increase our dividend annually. These actions to meet customer needs, market conditions and investor expectations reflect our long-term approach to managing our company. We continue our focus on operational excellence, financial strength and disciplined investment. These guiding principles have provided the base from which we have been able to execute our strategic initiatives.
Disciplined Investment
We utilize rigorous criteria when deploying capital and seek to invest in areas that complement our existing business and provide reasonable risk-adjusted returns. These areas include upgrading our energy infrastructure and improving our environmental footprint to align with public policy objectives. In the first three months of 2019, we

• | made additional investments in T&D infrastructure projects,

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

• | continued construction of our BH5 generation project, the final stage of our investment program in combined cycle gas turbines.

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 this Quarterly Report on Form 10-Q.
Transmission Planning
There are several matters pending before FERC that may impact the allocation of costs associated with transmission projects, including those being constructed by PSE&G. Regardless of how these proceedings are resolved, PSE&G’s ability to recover the costs of these projects will not be affected. However, the result of these proceedings could ultimately impact the amount of costs borne by customers in New Jersey. In addition, as a BGS supplier, Power provides services that include specified transmission costs. If the allocation of the costs associated with the transmission projects were to increase these BGS-related transmission costs, BGS suppliers would be entitled to recovery, subject to BPU approval. We do not believe that these matters will have a material effect on Power’s business or results of operations.
Several complaints have been filed and several remain pending at FERC against transmission owners around the country, challenging those transmission owners’ base return on equity (ROE). Certain of those complaints have resulted in decisions and others have been settled, resulting in reductions of those transmission owners’ base ROEs. The results of these other proceedings could set precedents for other transmission owners with formula rates in place, including PSE&G.
In October 2018, FERC issued an order establishing a new framework for determining whether a company’s ROE is unjust and unreasonable. FERC proposes to rely on financial models to establish a composite zone of reasonableness that will be used to determine whether an ROE complaint should be dismissed. If FERC determines that an ROE for a company is not just and reasonable, it intends to reset the ROE based on averaging the results of various financial models. We continue to analyze the potential impact of these methodologies and cannot predict the outcome of ongoing ROE proceedings.
In March 2019, FERC issued two Notices of Inquiry (NOI) that could affect a company’s ROE: (i) an NOI seeking comment on improvements to FERC’s electric transmission incentives policy to ensure that it appropriately encourages the development of the infrastructure needed to ensure grid reliability and reduce congestion to lower the cost of power for consumers (Incentive NOI), and (ii) an NOI seeking comments whether, and if so how, FERC should change its policies for establishing just and reasonable ROEs. The Incentive NOI is intended to examine whether existing incentives, such as the 50 basis point adder for Regional Transmission Organization membership, should continue to be granted and whether new incentives should be established.
Wholesale Power Market Design
In June 2018, FERC issued an order finding that PJM’s current capacity market is not just and reasonable because it enabled state-supported resources to bid below their costs which resulted in suppressed clearing prices. In particular, FERC found that nuclear generating units that receive zero emission certificate payments were of concern. Depending on the outcome of this matter, our generating stations could also be impacted.
In October 2018, PJM filed with FERC to revise the shape of the Variable Resource Requirement (VRR) curve that will be implemented for the capacity auction to be held in August 2019. The VRR curve is the administratively determined demand curve that serves as one of the key elements for establishing the amount of generation capacity to be procured in the
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auction. PJM’s proposed tariff revisions will result in lower Cost of New Entry (CONE) values as compared to the currently effective VRR curve. PSEG protested PJM’s proposal on the grounds that it would result in understated prices for capacity relative to the cost of constructing a new reference generating unit and will result in prices that are unjust and unreasonable. In April 2019, FERC issued an Order approving PJM’s filing without modification and these changes are expected to be in place for the 2022/2023 PJM capacity auction to be held in August 2019.
Environmental Regulation
We are subject to liability under environmental laws for the costs 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 of any such remediation efforts could be material.
In August 2018, the EPA released the proposed Affordable Clean Energy (ACE) rule as a replacement for the EPA’s Clean Power Plan. The proposed ACE rule gives states great flexibility to evaluate specific heat rate improvement technologies and practices to be applied at coal-fired electric generating units. States have three years from the date of finalization to submit a plan that establishes a standard of performance that reflects the degree of emission limitation through the application of heat rate improvement technologies and practices. We cannot estimate the impact of this action on our business or results of operations at this time.
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 May 2018, the governor of New Jersey signed legislation, referred to as the Zero Emission Certificate (ZEC) legislation, that recognizes that nuclear power is a critical component of New Jersey’s clean energy portfolio and an important element of a diverse energy generation portfolio that currently meets approximately 40 percent of New Jersey’s electric power needs. The ZEC legislation created a program administered by the BPU. The BPU established processes to provide for the purchase of ZECs from selected nuclear plants and recovery of those ZEC payments through a non-bypassable distribution charge (ZEC charge) in the amount of $0.004 per kilowatt-hour (which is equivalent to approximately $10 per megawatt hour (MWh)) in payments to selected nuclear plants.
In April 2019, Power’s Salem 1, Salem 2 and Hope Creek nuclear plants were awarded ZECs. As a result, the final “must-offer” exception requests and deactivation notices previously submitted to the PJM Independent Market Monitor and the PJM Office of Interconnection for the Salem and Hope Creek plants have been withdrawn. These nuclear plants are expected to receive ZEC revenue for approximately three years, through May 2022, and will be obligated to maintain operations, subject to exceptions specified in the ZEC legislation. Power anticipates it will recognize revenue monthly as the nuclear plants generate electricity and satisfy their performance obligations. The ZEC legislation requires nuclear plants to reapply for any subsequent three year periods. The ZEC payment may be adjusted by the BPU (a) at any time to offset environmental or fuel diversity payments that a selected nuclear plant may receive from another source or (b) at certain times specified in the ZEC legislation if the BPU determines that the purposes of the ZEC legislation can be achieved through a reduced charge that will nonetheless be sufficient to achieve the state’s air quality and other environmental objectives by preventing the retirement of nuclear plants. The financial condition of the plants may nonetheless be materially adversely impacted by potential changes to the capacity market construct being considered by FERC (absent sufficient capacity revenues provided under a program approved by the BPU in accordance with a FERC authorized capacity mechanism), and, 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. Absent a material financial change, these adverse impacts could still result in Power taking all necessary steps to retire all of these plants following the end of the initial three year term of the ZECs program. Retirement of these plants would result in a material adverse impact on PSEG’s and Power’s financial results.
In addition, in April 2019 Salem 1 began a scheduled refueling outage during which we planned to continue the replacement of degraded bolts inside the reactor vessel. Following an inspection and testing, it was revealed that a significantly larger number of bolts than initially anticipated will require replacement during this outage. As a result, we expect the duration of this outage to be longer than planned, which will impact Salem Unit 1’s production and margin, including the amount of ZEC payments received by Salem 1. Lower production at Salem 1 may be offset by increased production at our combined cycle generating stations.
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Fossil
PSEG and Power continue to monitor their other coal assets, including their interest in the Keystone and Conemaugh generating stations, to assess their economic viability through the end of their designated useful lives and their continued classification as held for use. The precise timing of a change in useful lives may be dependent upon events out of PSEG’s and Power’s control and may impact their ability to operate or maintain certain assets in the future. These generating stations may be impacted by factors such as environmental legislation, co-owner capital requirements and continued depressed wholesale power prices or capacity factors, among other things. Any early retirement or change in the classification as held for use of our remaining coal units may have a material adverse impact on PSEG’s and Power’s future financial results.
California Solar Facilities
As part of its solar production portfolio, Power owns and operates two California-based solar facilities with an aggregate capacity of approximately 30 MW direct current whose output is sold to Pacific Gas and Electric Company (PG&E) under power purchase agreements (PPAs) with twenty year terms. The net book value of these solar facilities was approximately $57 million as of March 31, 2019. In January 2019, PG&E and its parent company PG&E Corporation filed for Chapter 11 bankruptcy protection. Power cannot predict the ultimate outcome that this bankruptcy proceeding will have on our ability to collect all of the revenues from these facilities due under the PPAs; however, any adverse changes to the terms of Power’s PPAs as a result of this bankruptcy proceeding could result in the future impairment of these assets in amounts up to their current net book value.
Offshore Wind
In January 2018, the governor of New Jersey signed Executive Order No. 8 directing the BPU to begin the process of moving the state toward its 2030 goal of 3,500 MW of offshore wind energy generation. An initial solicitation was established for 1,100 MW of offshore wind, with bids due in December 2018. In connection with the bid submitted by Ocean Wind, LLC, a wholly owned subsidiary of Ørsted US Offshore Wind, referred to as the Ocean Wind project, PSEG agreed to provide energy management services and the potential lease of land for use in project development. We also retained an option to acquire an equity interest in the project. We expect to make a decision regarding an equity investment in the Ocean Wind project in the second half of 2019.
Leveraged Leases
In December 2018, NRG REMA, LLC emerged from its in-court proceeding under Chapter 11 of the Bankruptcy Code. As a result of the restructuring, the remaining deferred tax liabilities related to the Keystone and Conemaugh lease investments were reclassified to current tax liabilities. PSEG expects to pay approximately $120 million to taxing authorities resulting from this restructuring activity.
Additional facilities in our leveraged lease portfolio include the Shawville, Joliet and Powerton generating facilities. Converted natural gas units such as Shawville and Joliet may have higher operating costs and fuel consumption, as well as longer start-up times, compared to newer combined cycle gas units. Powerton is a coal-fired generating facility in Illinois. Each of these three facilities may not be as economically competitive as newer combined cycle gas units and could continue to be adversely impacted by the same economic conditions experienced by other less efficient natural gas and coal generation facilities, which could require Energy Holdings to write down the residual value of the leveraged lease receivables associated with these facilities.
Tax Legislation
The Tax Act, among other things, decreased the statutory U.S. corporate income tax rate from a maximum of 35% to 21%, effective January 1, 2018, and made certain changes to the bonus depreciation and interest disallowance rules.
In August 2018, the Internal Revenue Service (IRS) issued a Notice of Proposed Rulemaking (Notice) regarding the application of tax depreciation rules as amended by the Tax Act. While the Notice provides some guidance as to the application of the changes made by the Tax Act to the bonus depreciation rules, certain aspects remain unclear. Further, in November 2018 the IRS issued Proposed Regulations addressing the interest disallowance rules contained in the Tax Act. For non-regulated businesses, these rules set a cap on the amount of interest that can be deducted in a given year. Any amount that is disallowed can be carried forward indefinitely. For 2019, PSEG and Power expect that a portion of their interest will be disallowed in the current period but realized in future periods. However, certain aspects of the proposed regulations are unclear. Therefore, we recorded taxes based on our interpretation of the relevant statute. Such amounts are subject to change based on several factors, including but not limited to, the IRS and state taxing authorities issuing final guidance and/or further clarification. Any further guidance or clarification could impact PSEG’s, PSE&G’s and Power’s financial statements. For additional information, see Item 1. Note 16. Income Taxes.
In July 2018, the State of New Jersey made changes to its income tax laws, including imposing a temporary surtax of 2.5% effective January 1, 2018 and 2019 and 1.5% in 2020 and 2021, as well as requiring corporate taxpayers to file in a combined
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reporting group as defined under New Jersey law starting in 2019. Both provisions include an exemption for public utilities. We believe PSE&G meets the definition of a public utility and, therefore, will not be impacted by the temporary surtax or be included in the combined reporting group. We expect these new provisions to unfavorably affect our non-utility business. In accordance with accounting principles generally accepted in the United States for income taxes, deferred taxes are required to be measured at the enacted tax rate expected to apply to taxable income in the periods in which the deferred taxes are expected to settle. The newly enacted New Jersey tax legislation did not have a material impact on PSEG’s deferred income tax balance.
Future Outlook
Our future success will depend on our ability to continue to maintain strong operational and financial performance in an environment with low gas prices, 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 must continue to:

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

• | successfully manage our energy obligations and re-contract our open supply positions in response to changes in prices and demand,

• | obtain approval of and execute our utility capital investment program, including ES II, GSMP II, our CEF program and transmission and other investments that yield contemporaneous and reasonable risk-adjusted returns, while enhancing the resiliency of our infrastructure and maintaining the reliability of the service we provide to our customers,

• | effectively complete construction of BH5,

• | advocate for measures to ensure the implementation by PJM and FERC of market design and transmission planning rules that continue to promote fair and efficient electricity markets, including recognition of the cost of emissions,

• | engage multiple stakeholders, including regulators, government officials, customers and investors, and

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

In addition to the risks described elsewhere in this Form 10-Q and in our Form 10-K, for 2019 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 impacts of the Tax Act and changes in state tax laws, and

• | the impact of reductions in demand and lower natural gas and electricity prices and increasing environmental compliance costs.

We continually assess a broad range of strategic options to maximize long-term stockholder value. In assessing our options, we consider a wide variety of factors, including the performance and prospects of our businesses; the views of 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:

• | the acquisition, construction or disposition of T&D facilities, clean energy investments and/or generation projects, including offshore wind opportunities,

• | the disposition or reorganization of our merchant generation business or other existing businesses or the acquisition or development of new businesses,

• | the expansion of our geographic footprint, including the operation of T&D facilities outside of our traditional service territory, and

• | investments in capital improvements and additions, including the installation of environmental upgrades and retrofits, improvements to system resiliency, modernizing existing infrastructure and participation in transmission projects through FERC’s “open window” solicitation process.

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.
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RESULTS OF OPERATIONS
PSEG
Our results of operations are primarily comprised of the results of operations of our principal operating subsidiaries, PSE&G and 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/ (Decrease) |
|  | March 31, |  |
|  | 2019 |  | 2018 |  | 2019 vs. 2018 |
|  | Millions |  | Millions |  | % |
| Operating Revenues | $ | 2,980 |  |  | $ | 2,818 |  |  | $ | 162 |  |  | 6 |  |
| Energy Costs | 1,124 |  |  | 952 |  |  | 172 |  |  | 18 |  |
| Operation and Maintenance | 756 |  |  | 754 |  |  | 2 |  |  | — |  |
| Depreciation and Amortization | 314 |  |  | 280 |  |  | 34 |  |  | 12 |  |
| Income from Equity Method Investments | 2 |  |  | 2 |  |  | — |  |  | — |  |
| Net Gains (Losses) on Trust Investments | 128 |  |  | (22 | ) |  | 150 |  |  | N/A |  |
| Other Income (Deductions) | 33 |  |  | 32 |  |  | 1 |  |  | 3 |  |
| Non-Operating Pension and OPEB Credits (Costs) | 33 |  |  | 19 |  |  | 14 |  |  | 74 |  |
| Interest Expense | 133 |  |  | 103 |  |  | 30 |  |  | 29 |  |
| Income Tax Expense | 149 |  |  | 202 |  |  | (53 | ) |  | (26 | ) |

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

|  | Three Months Ended |  | Increase/ (Decrease) |
|  | March 31, |  |
|  | 2019 |  | 2018 |  | 2019 vs. 2018 |
|  | Millions |  | Millions |  | % |
| Operating Revenues | $ | 2,032 |  |  | $ | 1,845 |  |  | $ | 187 |  |  | 10 |  |
| Energy Costs | 947 |  |  | 782 |  |  | 165 |  |  | 21 |  |
| Operation and Maintenance | 408 |  |  | 391 |  |  | 17 |  |  | 4 |  |
| Depreciation and Amortization | 212 |  |  | 190 |  |  | 22 |  |  | 12 |  |
| Net Gains (Losses) on Trust Investments | 1 |  |  | — |  |  | 1 |  |  | N/A |  |
| Other Income (Deductions) | 19 |  |  | 20 |  |  | (1 | ) |  | (5 | ) |
| Non-Operating Pension and OPEB Credits (Costs) | 30 |  |  | 15 |  |  | 15 |  |  | 100 |  |
| Interest Expense | 87 |  |  | 81 |  |  | 6 |  |  | 7 |  |
| Income Tax Expense | 25 |  |  | 117 |  |  | (92 | ) |  | (79 | ) |

Three Months Ended March 31, 2019 as Compared to 2018
Operating Revenues increased $187 million due to changes in delivery, commodity, clause and other operating revenues.
Delivery Revenues decreased $22 million due primarily to

• | Gas, Electric and Transmission revenue requirements were reduced by $129 million due to the flowback of excess deferred tax liabilities and tax repair-related accumulated deferred income tax benefits as a result of settlements with the BPU and FERC. This reduction is offset in Income Tax Expense.

• | Gas distribution revenues increased $54 million due primarily to a $46 million increase due to the favorable impact of the distribution tariff rate effective November 2018, a $10 million increase from the inclusion of GSMP I in base rates,

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and a $9 million increase due to higher sales volumes. These increases were partially offset by decreases in 2019 of $9 million in Weather Normalization Clause collections and $2 million in Green Program Recovery Charges (GPRC).

• | Electric distribution revenues increased $29 million due to a $20 million increase resulting from the favorable impact of the distribution tariff rate, a $5 million increase due to higher sales volumes and a $4 million increase in GPRC collections.

• | Transmission revenues were $24 million higher due to revenue requirements calculated through our transmission formula rate.

Commodity Revenues increased $165 million as a result of higher Gas and 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 basic gas supply service (BGSS) and BGS to retail customers.

• | Gas commodity revenues increased $133 million due to higher BGSS prices of $94 million and higher BGSS sales volumes of $39 million.

• | Electric commodity revenues increased $32 million due primarily to $21 million in higher BGS sales volumes and $15 million in higher BGS prices. These increases were partially offset by $2 million decreases in each of sales of solar renewable energy credits and the Non-Utility Generation Charge.

Clause Revenues increased $47 million due to a $31 million increase in Tax Adjustment Credit (TAC) deferrals, higher Societal Benefit Charge (SBC) collections of $11 million and a $6 million increase in Margin Adjustment Clause (MAC) revenues. These increases were partially offset by a $1 million decrease in GPRC deferrals. The changes in the SBC and MAC collections 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 and Interest Expenses. PSE&G does not earn margin on SBC or MAC collections or on TAC or GPRC deferrals.
Operating Expenses
Energy Costs increased $165 million. This is entirely offset by the change in Commodity Revenues.
Operation and Maintenance increased $17 million due primarily to a net $26 million increase in clause and renewable related expenditures. This increase was partially offset by a $9 million reduction in seasonal storm costs.
Depreciation and Amortization increased $22 million due primarily to a $17 million increase in depreciation related to additional plant placed into service, an increase of $3 million in the amortization of Regulatory Assets and a $2 million increase due to revised depreciation rates effective November 2018.
Non-Operating Pension and OPEB Credits (Costs) reflect an increase of $15 million in credits due to a $26 million decrease in the amortization of the prior service cost, partially offset by an $8 million reduction in the long-term expected return on plan assets, a $2 million increase in the amortization of the net unrecognized loss and a $1 million increase in interest cost.
Interest Expense increased $6 million due primarily related to net debt issuances in May and September 2018.
Income Tax Expense decreased $92 million due primarily to the flowback of excess deferred income tax liabilities and tax repair-related accumulated deferred income taxes.
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Power

|  | Three Months Ended |  | Increase/ (Decrease) |
|  | March 31, |  |
|  | 2019 |  | 2018 |  | 2019 vs. 2018 |
|  | Millions |  | Millions |  | % |
| Operating Revenues | $ | 1,416 |  |  | $ | 1,403 |  |  | $ | 13 |  |  | 1 |  |
| Energy Costs | 786 |  |  | 746 |  |  | 40 |  |  | 5 |  |
| Operation and Maintenance | 235 |  |  | 246 |  |  | (11 | ) |  | (4 | ) |
| Depreciation and Amortization | 94 |  |  | 82 |  |  | 12 |  |  | 15 |  |
| Income from Equity Method Investments | 2 |  |  | 2 |  |  | — |  |  | — |  |
| Net Gains (Losses) on Trust Investments | 126 |  |  | (22 | ) |  | 148 |  |  | N/A |  |
| Other Income (Deductions) | 13 |  |  | 11 |  |  | 2 |  |  | 18 |  |
| Non-Operating Pension and OPEB Credits (Costs) | 3 |  |  | 4 |  |  | (1 | ) |  | (25 | ) |
| Interest Expense | 25 |  |  | 7 |  |  | 18 |  |  | N/A |  |
| Income Tax Expense (Benefit) | 124 |  |  | 83 |  |  | 41 |  |  | 49 |  |

Three Months Ended March 31, 2019 as Compared to 2018
Operating Revenues increased $13 million due primarily to changes in generation and gas supply revenues.
Gas Supply Revenues increased $37 million due primarily to

• | an increase of $52 million in sales under the BGSS contract, of which $30 million was due to higher average sales prices and $22 million to an increase in sales volumes during the 2019 winter heating season,

• | partially offset by a decrease of $18 million related to sales to third parties, of which $14 million was due to lower average sales prices and $4 million to lower volumes sold.

Generation Revenues decreased $24 million due primarily to

• | a net decrease of $44 million due to lower MTM gains in 2019 as compared to 2018. Of this amount, a $53 million decrease was due to gains on positions reclassified to realized upon settlement, partially offset by a $9 million increase from changes in forward prices this year as compared to last year, and

• | a net decrease of $39 million in electricity sold under our BGS contracts due to lower volumes and lower prices,

• | partially offset by a net increase of $48 million due primarily to higher volumes of electricity sold in the PJM region and under wholesale load contracts in the New England (NE) region, partially offset by lower average realized prices in the PJM region, and

• | a net increase of $14 million in capacity revenues due primarily to an increase in auction prices in the PJM region.

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 Power’s obligation under its BGSS contract with PSE&G. Energy Costs increased $40 million due to
Gas costs increased $41 million due mainly to

• | an increase of $50 million related to sales under the BGSS contract, of which $33 million was due to an increase in the average cost of gas and $17 million to an increase in send-out volumes during the 2019 winter heating season,

• | partially offset by a net decrease of $8 million related to sales to third parties due primarily to a decrease in volumes sold, partially offset by an increase in gas costs.

Generation costs decreased $1 million due primarily to

• | a decrease of $29 million due to MTM gains in 2019 as compared to losses in 2018 due to changes in forward prices, and

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• | a net decrease of $6 million from charges primarily related to additional retirement costs incurred in 2018 associated with early retirement of the Mercer and Hudson coal units,

• | partially offset by higher fuel costs of $27 million, reflecting utilization of higher volumes of gas, primarily due to the commencement of commercial operations of Keys and Sewaren 7 fossil stations in mid-2018, coupled with higher prices of gas in the PJM region, partially offset by the utilization of lower volumes and gas prices in the New York region, lower volumes of oil in the PJM region, and lower coal prices in the PJM and NE regions, and

• | a net increase of $7 million primarily due to higher volumes of energy purchased in the NE region to serve load obligations.

Operation and Maintenance decreased $11 million due primarily to

• | a $14 million net decrease at our fossil plants, largely due to higher planned outage costs in 2018,

• | partially offset by a net increase related to our nuclear plants, due primarily to planned outage costs incurred in 2019 for our 57%-owned Salem Unit 1 as compared to planned outage costs at our 100%-owned Hope Creek nuclear plant in 2018.

Depreciation and Amortization increased $12 million due primarily to Keys and Sewaren 7 fossil stations being placed into service.
Net Gains (Losses) on Trust Investments increased $148 million due primarily to a $133 million increase resulting from net unrealized gains in 2019 as compared to net unrealized losses in 2018 on equity investments in the NDT Fund and a $14 million increase in net realized gains on NDT Fund investments.
Interest Expense increased $18 million due primarily to $14 million in lower capitalized interest as a result of Keys and Sewaren 7 fossil stations being placed into service.
Income Tax Expense (Benefit) increased $41 million due primarily to higher pre-tax income in 2019, including income from the NDT qualified fund, which is subject to an additional trust tax.
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 expect our operating cash flows combined with cash on hand and financing activities to be sufficient to fund capital expenditures and shareholder dividend payments.
For the three months ended March 31, 2019, our operating cash flow increased $78 million as compared to the same period in 2018. The net changes were primarily due to the net changes from our subsidiaries as discussed below.
PSE&G
PSE&G’s operating cash flow decreased $57 million from $577 million to $520 million for the three months ended March 31, 2019, as compared to the same period in 2018, due primarily to a decrease of $143 million relating to accounts receivable and unbilled revenues due primarily to higher billings in 2019 reflecting increased prices and volumes and $96 million in increased vendor payments, offset by tax refunds in 2019, an increase of $75 million from a change in regulatory deferrals and higher earnings.
Power
Power’s operating cash flow increased $184 million from $542 million to $726 million for the three months ended March 31, 2019, as compared to the same period in 2018, due to a decrease in margin deposit requirements of $165 million, a $56 million increase in fuels, materials and supplies and higher earnings, partially offset by a $59 million decrease from net collections of counterparty receivables.
Short-Term Liquidity
PSEG meets its short-term liquidity requirements, as well as those of Power, primarily with cash and through the issuance of commercial paper. 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.
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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.
Our total credit facilities and available liquidity as of March 31, 2019 were as follows:

| Company/Facility |  | As of March 31, 2019 |
| Total Facility |  | Usage |  | Available Liquidity |
|  |  | Millions |
| PSEG |  | $ | 1,500 |  |  | $ | 802 |  |  | $ | 698 |  |
| PSE&G |  | 600 |  |  | 380 |  |  | 220 |  |
| Power |  | 2,100 |  |  | 143 |  |  | 1,957 |  |
| Total |  | $ | 4,200 |  |  | $ | 1,325 |  |  | $ | 2,875 |  |

As of March 31, 2019, our credit facility capacity was in excess of our projected maximum liquidity requirements over our 12 month planning horizon. Our maximum liquidity requirements are based on stress scenarios that incorporate changes in commodity prices and the potential impact of Power losing its investment grade credit rating from S&P or Moody’s, which would represent a three level downgrade from its current S&P or Moody’s ratings. In the even t of a deterioration of Power’s credit rating certain of 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 Power were to lose its investment grade credit rating was approximately $850 million and $857 million as of March 31, 2019 and December 31, 2018, respectively.
For additional information, see Item 1. Note 12. Debt and Credit Facilities.
Long-Term Debt Financing
During the next twelve months, PSEG has $400 million of 1.60% Senior Notes maturing in November 2019. PSE&G has $250 million of 1.80% Medium Term Notes maturing in June 2019 and $250 million of 2.00% Medium Term Notes maturing in August 2019.
For additional information see Item 1. Note 12. Debt and Credit Facilities.
Common Stock Dividends
On April 16, 2019, our Board of Directors declared a $0.47 dividend per share of common stock for the second quarter of 2019. This reflects an indicative annual dividend rate of $1.88 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 Corporate Credit Ratings (S&P) and Issuer Credit Ratings (Moody’s) and can be Stable, Negative, or Positive. 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.
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|  |  | Moody’s (A) |  | S&P (B) |
| PSEG |  |  |  |  |
| Outlook |  | Stable |  | Stable |
| Senior Notes |  | Baa1 |  | BBB |
| Commercial Paper |  | P2 |  | A2 |
| PSE&G |  |  |  |  |
| Outlook |  | Stable |  | Stable |
| Mortgage Bonds |  | Aa3 |  | A |
| Commercial Paper |  | P1 |  | A2 |
| 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 Form 10-K. See Executive Overview of 2019 and Future Outlook for additional information.
PSE&G
During the three months ended March 31, 2019, PSE&G made capital expenditures of $630 million, primarily for T&D system reliability. This does not include expenditures for cost of removal, net of salvage, of $30 million, which are included in operating cash flows.
Power
During the three months ended March 31, 2019, Power made capital expenditures of $156 million, excluding $11 million for nuclear fuel, primarily related to our BH5 and other generation 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. 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
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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 January through March 2019, MTM VaR was relatively stable between a low of $6 million and a high of $35 million at the 95% confidence level. The range of VaR was narrower for the three months ended March 31, 2019 as compared with the year ended December 31, 2018.

|  |  | MTM VaR |
|  |  | Three Months Ended March 31, 2019 |  | Year Ended December 31, 2018 |
|  |  | Millions |
| 95% Confidence Level, Loss could exceed VaR one day in 20 days |  |  |  |  |
| Period End |  | $ | 8 |  |  | $ | 21 |  |
| Average for the Period |  | $ | 15 |  |  | $ | 14 |  |
| High |  | $ | 35 |  |  | $ | 46 |  |
| Low |  | $ | 6 |  |  | $ | 6 |  |
| 99.5% Confidence Level, Loss could exceed VaR one day in 200 days |  |  |  |  |
| Period End |  | $ | 12 |  |  | $ | 32 |  |
| Average for the Period |  | $ | 23 |  |  | $ | 22 |  |
| High |  | $ | 54 |  |  | $ | 72 |  |
| Low |  | $ | 9 |  |  | $ | 9 |  |

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 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 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 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 Power
There have been no changes in internal control over financial reporting that occurred during the first quarter of 2019 that have materially affected, or are reasonably likely to materially affect, each registrant’s internal control over financial reporting.
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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.

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. There have been no material changes to the risk factors set forth in the above-referenced filings as of March 31, 2019.

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

In December 2018, 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 vest or be exercised in 2019. The following table indicates our common share repurchases in the open market during the first quarter of 2019.

| Three Months Ended March 31, 2019 |  | Total Number of Shares Purchased |  | Average Price Paid per Share |
| January 1 - January 31 |  | 900,000 |  |  | $ | 51.15 |  |
| February 1 - February 28 |  | — |  |  | $ | — |  |
| March 1 - March 31 |  | — |  |  | $ | — |  |

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. References are to the related pages on the Form 10-K as printed and distributed.
Federal Regulation
Energy Clearing Prices
December 31, 2018 From 10-K page 15. As part of its broader initiative regarding energy market price formation rules, in April 2019 FERC issued a final Order on fast-start pricing applicable to resources in PJM and the New York ISO (NYISO). 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 has required that each of PJM and NYISO 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. We will continue to participate in this process before FERC.
December 31, 2018 From 10-K page 16. In March 2019, PJM filed a proposal under section 206 of the Federal Power Act to modify the curves used for pricing reserves with FERC. The reforms include a consolidation of synchronized reserve products, improved use of existing capability for locational reserve needs, better alignment of reserve products in day-ahead and real-time markets, a downward-sloping operating reserve demand curve, and increased penalty factors to ensure use of all supply prior to a reserve shortage. If placed into effect, these reforms are expected to improve energy and reserve prices by ensuring that when operators commit resources to ensure reliability, the commitments are reflected in market clearing prices. However, these reforms could result in lower capacity payments. There is no timeline for this type of filing and therefore we cannot predict when FERC will act on the filing or the outcome of this matter.
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Capacity Market Issues
December 31, 2018 Form 10-K page 16. In October 2018, PJM filed with FERC to revise the shape of the VRR curve that will be implemented for the capacity auction to be held in August 2019. The VRR curve is the administratively determined demand curve that serves as one of the key elements for establishing the amount of generation capacity to be procured in the auction. PJM’s proposed tariff revisions will result in lower CONE values as compared to the currently effective VRR curve. PSEG protested PJM’s proposal on the grounds that it would result in understated prices for capacity relative to the cost of constructing a new reference generating unit and will result in prices that are unjust and unreasonable. In April 2019, FERC issued an Order approving PJM’s filing without modification and these changes are expected to be in place for the 2022/2023 PJM capacity auction to be held in August 2019.
Transmission Regulation-Transmission Policy Developments
December 31, 2018 Form 10-K page 17. There are several matters pending before FERC that concern the allocation of costs associated with transmission projects contending that insufficient levels of costs are being allocated to customers in the PSE&G transmission zone. Projects involved include the Artificial Island project and the Bergen-Linden Corridor (BLC) project in New Jersey. In April 2016, FERC issued orders denying the complaints and leaving the current cost allocation in effect as to the Bergen-Linden project. The BLC order is subject to a pending rehearing request. In March 2019, FERC issued an order establishing an alternative cost allocation methodology for the Artificial Island project. This resulted in increased costs being allocated to the PSE&G zone.
Another proceeding is a matter remanded from a federal appellate court concerning the appropriate cost allocation for certain 500 kilovolt (kV) projects in PJM that either have been built or are in the process of being built. In May 2018, FERC approved a settlement for this matter that is expected to result in increased annual cost allocations to customers in the PSE&G transmission zone. The cost reallocation was implemented by PJM in July 2018. Under this settlement, Power, as a BGS supplier is obligated to pay amounts previously paid by other PJM transmission customers. The approved settlement is subject to a pending rehearing request.
Transmission Regulation—Transmission Rate Proceedings and Return on Equity (ROE)
December 31, 2018 Form 10-K page 17. In October 2018, FERC issued an order establishing a new framework for determining whether a company’s ROE is unjust and unreasonable. FERC proposes to rely on financial models to establish a composite zone of reasonableness that will be used to determine whether an ROE complaint should be dismissed. If FERC determines that an ROE for a company is not just and reasonable, it intends to reset the ROE based on averaging the results of various financial models.
In March 2019, FERC issued two NOIs that could affect a company’s ROE: (i) an NOI seeking comment on improvements to FERC’s electric transmission incentives policy to ensure that it appropriately encourages the development of the infrastructure needed to ensure grid reliability and reduce congestion to lower the cost of power for consumers (Incentive NOI) and (ii) an NOI seeking comments whether, and if so how, FERC should change its policies for establishing just and reasonable ROEs. The Incentive NOI is intended to examine whether existing incentives, such as the 50 basis point adder for RTO membership, should continue to be granted and whether new incentives should be established. The Incentive NOI includes the consideration of incentives for economic efficiency and reliability benefits, RTO membership, improvements to existing transmission facilities, consideration of the costs and benefits of projects in awarding incentives, and determination of whether to review incentive applications on a case-specific or standardized basis. While we cannot predict the outcome of ongoing transmission ROE proceedings, an adverse change to PSE&G’s base transmission ROE or ROE incentives could be material.
BGSS Process
December 31, 2018 Form 10-K page 19. In November 2017, the Retail Energy Supply Association (RESA) made a filing with the BPU requesting that the BPU revisit the BGSS process and establish a gas capacity release program. In March 2018, the RESA filed an amended petition with the BPU requesting a formal proceeding to establish a gas capacity release program. This filing applied to all New Jersey gas utilities. In late February 2019, the BPU found that RESA had not demonstrated that the gas utilities have sufficient excess capacity to create the type of release program proposed by RESA and determined to close the proceeding commenced by RESA’s filing.
As a result of representations made by RESA regarding concerns over sufficient gas capacity for all New Jersey customers, including those served by third party suppliers, the BPU opened a stakeholder proceeding. This proceeding will explore whether sufficient gas capacity has been secured to serve all New Jersey natural gas customers, whether served through BGSS or a third party supplier. In addition, the proceeding will review whether, and to what extent, third party suppliers are providing savings to New Jersey customers on their natural gas supply.
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ITEM 6. | EXHIBITS

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

a. PSEG: |  |
Exhibit 10: |  | Key Executive Severance Plan of Public Service Enterprise Group Incorporated, amended effective April 15, 2019
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: |  | XBRL Instance Document
Exhibit 101.SCH: |  | XBRL Taxonomy Extension Schema
Exhibit 101.CAL: |  | XBRL Taxonomy Extension Calculation Linkbase
Exhibit 101.LAB: |  | XBRL Taxonomy Extension Labels Linkbase
Exhibit 101.PRE: |  | XBRL Taxonomy Extension Presentation Linkbase
Exhibit 101.DEF: |  | XBRL Taxonomy Extension Definition Document
b. PSE&G: |  |
Exhibit 10: |  | Key Executive Severance Plan of Public Service Enterprise Group Incorporated, amended effective April 15, 2019
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: |  | XBRL Instance Document
Exhibit 101.SCH: |  | XBRL Taxonomy Extension Schema
Exhibit 101.CAL: |  | XBRL Taxonomy Extension Calculation Linkbase
Exhibit 101.LAB: |  | XBRL Taxonomy Extension Labels Linkbase
Exhibit 101.PRE: |  | XBRL Taxonomy Extension Presentation Linkbase
Exhibit 101.DEF: |  | XBRL Taxonomy Extension Definition Document
c. Power: |  |
Exhibit 10: |  | Key Executive Severance Plan of Public Service Enterprise Group Incorporated, amended effective April 15, 2019
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
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: |  | XBRL Instance Document
Exhibit 101.SCH: |  | XBRL Taxonomy Extension Schema
Exhibit 101.CAL: |  | XBRL Taxonomy Extension Calculation Linkbase
Exhibit 101.LAB: |  | XBRL Taxonomy Extension Labels Linkbase
Exhibit 101.PRE: |  | XBRL Taxonomy Extension Presentation Linkbase
Exhibit 101.DEF: |  | XBRL Taxonomy Extension Definition Document

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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.

P UBLIC S ERVICE E NTERPRISE G ROUP I NCORPORATED
(Registrant)
By: | /S/ R OSE M. C HERNICK
| Rose M. Chernick Vice President and Controller (Principal Accounting Officer)

Date: May 2, 2019
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.

P UBLIC S ERVICE E LECTRIC A ND G AS C OMPANY
(Registrant)
By: | /S/ R OSE M. C HERNICK
| Rose M. Chernick Vice President and Controller (Principal Accounting Officer)

Date: May 2, 2019
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 P OWER LLC
(Registrant)
By: | /S/ R OSE M. C HERNICK
| Rose M. Chernick Vice President and Controller (Principal Accounting Officer)

Date: May 2, 2019
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