PUBLIC SERVICE ENTERPRISE GROUP, INC. This combined MD&A is separately filed byPublic Service Enterprise Group Incorporated (PSEG),Public Service Electric and Gas Company (PSE&G) andPSEG Power LLC (PSEG Power ). Information contained herein relating to any individual company is filed by such company on its own behalf.PSE&G andPSEG 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
Commission (FERC). PSE&G also invests in regulated solar generation
projects and energy efficiency and related programs in
are regulated by the BPU, and
•
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,
generation in various states. PSEG Power's subsidiaries are subject to
regulation by FERC , the Nuclear Regulatory Commission (NRC), the
Environmental Protection Agency (EPA ) and the states in which they
operate.
PSEG's other direct wholly owned subsidiaries are: PSEG Long Island LLC (PSEG
LI), which operates the Long Island Power Authority's (LIPA) transmission and
distribution (T&D) system under an 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 2019 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 2019 and
Future Outlook provided in Item 7 in our Form 10-K by describing significant
events and business developments that have occurred during 2020 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 2020 AND FUTURE OUTLOOK
Our business plan is designed to achieve growth while managing the risks
associated with regulatory changes, fluctuating commodity prices and changes in
customer demand. Over the past few years, our investments have altered our
business mix to reflect a higher percentage of earnings contribution by PSE&G.
PSE&G, PSEG Power and PSEG LI continue to provide essential services during the
ongoing coronavirus (COVID-19) pandemic. We have implemented a comprehensive set
of enhanced safety actions to help protect our employees, customers and
communities, and we will continue to closely monitor developments and adjust as
needed to ensure that we continue to provide reliable service while protecting
the safety and health of our workforce and the communities we serve. We continue
to be guided by the recommendations of health authorities at the federal, state
and local levels. Employees who can perform their job duties remotely are doing
so. Those employees who must report to a work site are wearing personal
protective equipment (PPE) and practicing physical distancing measures.
Extensive cleaning protocols are also in place. Earlier this year, we suspended
non-essential work activities, while continuing to respond to customer outages
and requests for emergency service as well as infrastructure maintenance and
upgrades. As New Jersey has relaxed its coronavirus response protocols over the
past few months, we have initiated a phased re-starting of certain of these
activities (i.e., inside premises appliance repair and monthly meter reading
activities), while maintaining protocols for physical distancing and PPE.
Similarly, we have also begun to formulate policies and protocols for the
responsible reopening of our offices and work sites. Our "responsible reentry"
policies and protocols will continue to focus on the health and safety of our
employees, customers and the communities we serve while also taking a cautious
and measured approach toward reopening. We are continuing to assess the
appropriate timeline for this process. In connection with their reopening plans,
New Jersey , New York and Connecticut have issued advisories for anyone returning
from states that have a significant degree of community-wide spread of COVID-19,
referred to as "designated states." These advisories include exceptions for
essential employees and we are assessing what impact this may have on members of
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our workforce who may live in a designated state. We are also using enhanced physical distancing and safety protocols where there are impacts on members of our workforce who may live in or travel from a designated state. The ongoing coronavirus pandemic has not had a material impact on our results of operations, financial condition or cash flows for the six months endedJune 30, 2020 . However, the potential future impact of the pandemic and the associated economic impacts, which could extend beyond the duration of the pandemic, will depend on a number of factors outside of our control, including the duration and severity of the outbreak as well as third-party actions taken to contain its spread and mitigate its public health effects. While we currently cannot estimate the potential impact to our results of operations, financial condition and cash flows, this MD&A includes a discussion of potential effects of a prolonged outbreak. PSE&G At PSE&G, our focus is on enhancing reliability and resiliency of our T&D system, meeting customer expectations and supporting public policy objectives by investing capital in T&D infrastructure and clean energy programs. For the five-year period endingDecember 31, 2024 , PSE&G expects to invest between$11.5 billion to$15 billion , resulting in an expected compound annual rate base growth of 6.5% to 8%. These ranges are driven by certain unapproved investment programs, including the Clean Energy Future (CEF) program and incremental reliability and resiliency investments anticipated in the 2024 timeframe that we intend to seek approval for under the third phase of existing infrastructure programs. See below for a description of the CEF program. In 2019, we commenced our BPU-approved 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 approved by the BPU, PSE&G agreed to file for a base rate proceeding no later thanDecember 2023 , to maintain a base level of gas distribution capital expenditures of$155 million per year and to achieve certain leakage reduction targets. Also in 2019, the BPU approved our Energy Strong II Program (ES II ), an$842 million program to harden, modernize and improve the resiliency of our electric and gas distribution systems. This program began in the fourth quarter of 2019 and is expected to be completed by the end of 2023. Approximately$692 million of the program will be recovered through periodic rate recovery filings, with the balance to be recovered in our next distribution base rate case. InOctober 2018 , we filed our proposed 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 underNew Jersey's Clean Energy law; (ii) an Electric Vehicle (EV) infrastructure program; (iii) an Energy Storage (ES) program, which was submitted to the BPU together with the EV infrastructure program in a single filing; and (iv) an Energy Cloud (EC) program which will include installing approximately two million electric smart meters and associated infrastructure. InJanuary 2020 ,New Jersey released its Energy Master Plan (EMP) which, among other things, recognizes the importance of the State's EE targets and supported EVs, ES, and advanced metering infrastructure (AMI). InFebruary 2020 , PSE&G reached an agreement with parties in the CEF-EE matter which was approved by the BPU to (a) extend several existing EE programs for six months, with an additional$111 million investment over the course of the programs, and (b) extend the timeline for review of the CEF-EE filing throughSeptember 2020 . InJune 2020 , the BPU completed its stakeholder proceedings into certain aspects of EE and issued a final order outlining its policies, including which EE programs the State will manage and which will be managed by the State's utilities, as well as the utility cost recovery features, such as return on equity, amortization period, lost revenue recovery and potential incentives and penalties. The BPU's order is being employed in the resolution of PSE&G's pending CEF-EE filing. The BPU has also issued procedural schedules for the CEF-EC and CEF-EV/ES investment programs, both providing for evidentiary hearings in the fourth quarter of 2020. InApril 2020 , PSE&G filed with the BPU an update of its CEF-EC petition to revise certain assumptions, including an updated deployment schedule based on the procedural schedule. 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 2020-2022 is$2.8 billion . As noted above, PSE&G has been deemed byNew Jersey to provide essential services during the ongoing coronavirus pandemic. Our capital programs, including GSMP II,ES II and our transmission infrastructure investments, have not been materially impacted to date. However, a prolonged outbreak and the associated economic impacts, which could extend beyond the duration of the pandemic, could impact our ability to obtain necessary permits and approvals and could lead to shortages of necessary materials, supplies and labor. In addition, a determination by any state or federal regulatory authority that one or all of our projects is non-essential could require us to temporarily halt work. Any delay in our planned capital program could 72 --------------------------------------------------------------------------------
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impact our operational performance and could materially impact our results of operations and financial condition through decreased cost recovery. Further, the ongoing coronavirus pandemic has led many state and federal agencies to implement remote working protocols and divert resources to address the pandemic which, if prolonged, could impact regulatory agencies' ability to review proposed programs and delay the timing of approvals for matters subject to regulatory approval, including our CEF program that is currently before the BPU and the approval of various clause recovery mechanisms. PSE&G has experienced a reduction in demand from its commercial and industrial (C&I) customers, partially offset by increases in residential demand, and adverse changes to residential and C&I payment patterns, and expects these changes to continue during a prolonged coronavirus pandemic. In addition, PSE&G has informed both its residential customers and state regulators that all non-safety related service disconnections for non-payment have been temporarily suspended. As a result, PSE&G has seen a significant decrease in cash inflow and higher Accounts Receivable aging and an associated increase in bad debt expense, which we expect could extend beyond the duration of the coronavirus pandemic. PSE&G's electric distribution bad debt expense is recoverable through its Societal Benefits Clause (SBC) mechanism. Gas distribution bad debt expense in excess of what is included in base rates could adversely impact PSE&G's utility results from operations. Further, the implementation of actions to protect customers and employees, including physical distancing, mandatory PPE, and realignment of work crews, may have an adverse impact on operations and maintenance (O&M) costs. In addition, PSE&G has experienced a significant increase in the number of estimated C&I and residential customer bills, resulting from measures imposed byNew Jersey to limit the spread of COVID-19, which prevented PSE&G from physically entering customer properties to read meters. As part of theNew Jersey's phased reopening plan, this limitation was lifted inJuly 2020 . PSE&G expects to read the majority of customer meters in the third quarter of 2020 and make any appropriate adjustments to the amounts of customer bills relative to prior estimates, which adjustments are not expected to be material. InJuly 2020 , the BPU authorized regulated utilities inNew Jersey , including PSE&G, to create a COVID-19-related Regulatory Asset by deferring on their books and records the prudently incurred incremental costs related to COVID-19 beginning onMarch 9, 2020 throughSeptember 30, 2021 , or 60 days after theNew Jersey governor determines that the Public Health Emergency is no longer in effect, or in the absence of such a determination, 60 days from the time the Public Health Emergency automatically terminates by law, whichever is later. Deferred costs are to be offset by any federal or state assistance that the utility may receive as a direct result of the COVID-19 pandemic. PSE&G is evaluating the order and the deferral amounts that would be allowed under the order and expects to record a deferral commencing in the third quarter of 2020. While the impact on our results of operations, financial condition and cash flows for the six months endedJune 30, 2020 has not been material, a prolonged coronavirus pandemic and the associated economic impacts, which could extend beyond the duration of the pandemic, could materially impact cash from operations, Accounts Receivable and bad debt expense.PSEG Power At PSEG Power , we strive to improve performance and manage costs in order to optimize cash flow generation from our fleet in light of low wholesale power and gas prices, environmental considerations and competitive market forces that reward efficiency and reliability.PSEG Power continues to move its fleet toward improved efficiency and believes that its recently completed investment program enhances its competitive position with the addition of efficient, clean, reliable combined cycle gas turbine capacity. In the first six months of 2020, our natural gas and nuclear units generated 10.1 and 15.8 terawatt hours and operated at a capacity factor of 44.3% and 93.4%, respectively. Our commitments for load, such as basic generation service (BGS) inNew Jersey and other bilateral supply contracts, are backed by this generation or may be combined with the use of physical commodity purchases and financial instruments from the market to optimize the economic efficiency of serving our obligations.PSEG Power's hedging practices and ability to capitalize on market opportunities help it to balance some of the volatility of the merchant power business. More than 70% ofPSEG Power's expected gross margin in 2020 relates to hedging of our energy margin, our expected revenues from the capacity market mechanisms, Zero Emission Certificate (ZEC) revenues that commenced inApril 2019 and certain ancillary service payments such as reactive power. As discussed further below under "Wholesale Power Market Design,"FERC issued an order establishing new rules for PJM's capacity market, extending the PJM MinimumOffer Price Rule (MOPR) to include both new and existing resources that receive or are entitled to receive certain out-of-market payments, with certain exemptions.PSEG Power's New Jersey nuclear plants that receive ZEC payments will be subject to the new MOPR. In addition, as a result ofFERC's finding that default procurement auctions such as BGS could be considered subsidies, it is possible that other PSEG units could be subject to the MOPR. The MOPR's floor prices are not expected to prevent either our nuclear or gas-fired units from clearing in the next Reliability Pricing Model (RPM) auction. We cannot predict whether additional changes will be made to the MOPR, or whether changes will occur in the PJM market that would impact our ability to clear any of these units in future RPM auctions. In the first half of 2020, as a result of the ongoing coronavirus pandemic,PSEG Power experienced a decrease in aggregate wholesale electric demand. An extended outbreak could have a material adverse impact on future results of operations and cash flows. 73 --------------------------------------------------------------------------------
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PSEG Power has also implemented protocols to ensure the safety and health of employees at its generation facilities and contractors working at the facilities during planned outages. A prolonged unavailability of employees and contractors due to the ongoing coronavirus pandemic could materially and adversely impact our ability to operate our generation facilities, which would have a material impact on our business, results of operations and cash flows. Strategic Alternatives forPSEG Power's Non-Nuclear Fleet OnJuly 31, 2020 , PSEG announced that it is exploring strategic alternatives forPSEG Power's non-nuclear generating fleet, which includes more than 6,750 megawatts (MW) of fossil generation located inNew Jersey ,Connecticut ,New York andMaryland as well as the 467 MW Solar Source portfolio located in various states. An exit from the fossil generation business would accelerate PSEG's transition to a primarily regulated and contracted business, with a zero-carbon generation platform. It is expected to reduce overall business risk and earnings volatility, improve PSEG's credit profile and is consistent with PSEG's climate strategy and sustainability efforts, which is to focus on clean energy investments, methane reduction, and zero carbon generation. PSEG intends to retain ownership ofPSEG Power's existing nuclear fleet. While the company is in the preliminary stage of this evaluation, the marketing of a potential transaction in one or a series of steps, anticipated to launch in the fourth quarter of this year, is expected to be completed sometime in 2021. There is no assurance that the strategic review will result in a sale or other disposition of all or any portion of these assets on terms that are favorable to us, or at all. Any transaction would be subject to market conditions and customary closing conditions, including the receipt of all required regulatory approvals. Climate Strategy and Sustainability Efforts For more than a century, our mission has been to provide safe access to an around-the-clock supply of reliable, affordable power. Building on this mission, we believe in a future where customers universally use less energy, the energy they use is cleaner, and its delivery is more reliable and more resilient. InJuly 2019 , we announced that we expect to cut carbon emissions atPSEG Power's generation fleet by 80% by 2046, from 2005 levels. We have also announced our vision of attaining net-zero carbon dioxide (CO2) emissions by 2050, assuming advances in technology, public policy and customer behavior. PSE&G has also undertaken a number of initiatives that support the reduction of greenhouse gas (GHG) emissions and the implementation of energy efficiency initiatives. The first phase of our GSMP replaced approximately 450 miles of cast-iron and unprotected steel gas infrastructure, and the second phase of this program is expected to replace an additional 875 miles of gas pipes through 2023. The GSMP is designed to significantly reduce gas leaks in our distribution system, which would reduce the release of methane, a GHG, into the air. In addition, PSE&G's CEF proposals, which are under review by the BPU, are intended to supportNew Jersey's EMP through programs designed to help customers increase their energy efficiency, support the expansion of the electric vehicle infrastructure in the State, install energy storage capacity to supplement solar generation and enhance grid resiliency, install smart meters and supporting infrastructure to allow for the integration of other clean energy technologies and to more efficiently respond to weather and other outage events. 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 six months of 2020, our • utility continued its efforts to control costs while maintaining strong operational performance and has implemented protocols to ensure that we are providing essential services to our customers during the ongoing coronavirus pandemic in a safe and reliable manner, and
• efficient combined cycle gas units improved our capacity factor across the
natural gas fleet and were readily available to operate when needed, all
while diligently managing costs.
Financial Strength
Our financial strength is predicated on a solid balance sheet, positive
operating cash flow and reasonable risk-adjusted returns on increased
investment. Our financial position remained strong during the first six months
of 2020 as we
• maintained sufficient liquidity,
• maintained solid investment grade credit ratings, and
• increased our indicative annual dividend for 2020 to
InMarch 2020 , PSEG entered into a$300 million , 364-day term loan agreement and inApril 2020 it entered into two 364-day term loan agreements for$200 million and$300 million . These term loans provide an additional source of liquidity for our operations as we continue to monitor the impact of the ongoing coronavirus pandemic on the volatility and availability of the capital and commercial paper markets. We expect to be able to fund our planned capital requirements, as described in Liquidity and Capital Resources, and the impacts 74 --------------------------------------------------------------------------------
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of the Tax Cuts and Jobs Act of 2017 (Tax Act) without the issuance of new equity. Financial Results The results for PSEG,PSE&G andPSEG Power for the three months and six months endedJune 30, 2020 and 2019 are presented as follows: Three Months Ended Six Months Ended June 30, June 30, Earnings (Losses) 2020 2019 2020 2019 Millions PSE&G$ 283 $ 227 $ 723 $ 630 PSEG Power (A) 170 (40 ) 183 256 Other (B) (2 ) (34 ) (7 ) (33 ) PSEG Net Income$ 451 $ 153 $ 899 $ 853 PSEG Net Income Per Share (Diluted)$ 0.89 $ 0.30 $ 1.77 $ 1.68 (A) Includes an after-tax impairment charge of$284 million in the three months and six months endedJune 30, 2019 related to the sale of PSEG
Power's interests in the Keystone and Conemaugh fossil generation plants.
See Item 1. Note 4. Early Plant Retirements/Asset Dispositions for
additional information.
(B) Other includes after-tax activities at the parent company, PSEG LI, and
recorded an after-tax charge of $32 million in the second quarter of 2019
related to its investment in leveraged leases. See Item 1. Note 8.
Financing Receivables for additional information.
PSEG Power's results above include the Nuclear Decommissioning Trust (NDT) Fund
activity and the impacts of non-trading commodity mark-to-market (MTM) activity,
which consist of the financial impact from positions with future delivery dates.
The variances in our Net Income attributable to changes related to the NDT Fund
and MTM are shown in the following table:
Three Months Ended Six Months Ended
June 30, June 30,
2020 2019 2020 2019
Millions, after tax
NDT Fund Income (Expense) (A) (B)
Non-Trading MTM Gains (Losses) (C)
$ 228
(A) NDT Fund Income (Expense) includes gains and losses on NDT securities
which are recorded in
Note 9. Trust Investments for additional information. NDT Fund Income
(Expense) also includes interest and dividend income and other costs
related to the
accretion expense on
(ARO) recorded in 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 $(74) million and $(16) million for the
three months and $10 million and $(67) million for the six months ended
June 30, 2020 and 2019, respectively.
(C) Net of tax (expense) benefit of $30 million and $(58) million for the
three months and $0 million and $(88) million for the six months ended
June 30, 2020 and 2019, respectively.
Our $298 million increase in Net Income for the three months ended June 30, 2020
was driven primarily by
• an asset impairment in 2019 related to the sale of PSEG Power's interests
in the Keystone and Conemaugh fossil generation plants (see Item 1. Note
4. Early Plant Retirements/Asset Dispositions),
• higher net unrealized gains in 2020 on equity securities in the
at
• higher earnings due to investments in T&D programs at PSE&G, and
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• an impairment charge in 2019 related to a leveraged lease investment at
Our$46 million increase in Net Income for the six months endedJune 30, 2020 was driven primarily by • the above mentioned asset impairment in 2019 related to the sale of PSEG
Power's interests in the Keystone and Conemaugh fossil generation plants,
• higher earnings due to investments in T&D programs at PSE&G, and
• higher pension and OPEB credits,
• partially offset by MTM gains in 2019 at
• net unrealized losses in 2020 as compared to net unrealized gains on
equity securities in the NDT Fund at PSEG Power .
The greater emphasis on capital spending in recent years for projects at PSE&G
relative to PSEG Power , particularly those on which we receive contemporaneous
returns at PSE&G has yielded strong results, which when combined with the cash
flow generated by PSEG Power , has allowed us to meet customer needs and address
market conditions and investor expectations, reflecting 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 and consider a number of external factors,
including the economic impact of the ongoing coronavirus pandemic, when
determining how and when to efficiently deploy capital. We principally explore
opportunities for investment in areas that complement our existing business and
provide reasonable risk-adjusted returns. In the first six months of 2020, we
• made additional investments in T&D infrastructure projects on time and on
budget,
• continued to execute our Energy Efficiency and other existing BPU-approved
utility programs, and
• continued to evaluate a potential investment in offshore wind.
Regulatory, Legislative and Other Developments In our pursuit of operational excellence, financial strength and disciplined investment, we closely monitor and engage with stakeholders on significant regulatory and legislative developments. Transmission planning rules and wholesale power market design are of particular importance to our results and we continue to advocate for policies and rules that promote fair and efficient electricity markets. For additional information about regulatory, legislative and other developments that may affect us, see Part I, Item 1. Business-Regulatory Issues in our Form 10-K and Item 5. Other Information in our Quarterly Report on Form 10-Q for the period endingMarch 31, 2020 (first quarter 2020 10-Q) and this Quarterly Report on Form 10-Q. Transmission Rate Proceedings and Return on Equity (ROE) InMarch 2020 ,FERC issued a Notice of Proposed Rulemaking (NOPR) proposing to revise its electric transmission incentive policy to encourage the development of infrastructure needed to ensure grid reliability and reduce congestion to lower the cost of power for consumers. The NOPR proposes to shift the focus in granting incentives from an approach based on the risks and challenges faced by a project to an approach based on economic and reliability benefits to consumers. The NOPR proposes to retain several existing incentives, increase the 50 basis point adder forRegional Transmission Organization (RTO) participation to 100 basis points and provide incentives for transmission technologies that enhance reliability, efficiency and capacity. InMay 2020 ,FERC issued an order revising an earlier order that established a new ROE policy for reviewing existing transmission ROEs. The revised methodology uses the Discounted Cash Flow (DCF) model, the Capital Asset Pricing model (CAPM) and the risk premium model to determine if an existing base ROE is unjust and unreasonable and, if so, what replacement ROE is appropriate.FERC's order indicated that it would not be bound by this revised methodology when considering the just and reasonableness of a utility's ROE in future proceedings. We continue to analyze the potential impact of these methodologies. ROE complaints have been pending beforeFERC regarding MISO transmission owners, theISO New England Inc. transmission owners and utilities in other jurisdictions. In addition, over the past few years, several companies have negotiated settlements that have resulted in reduced ROEs. We are engaged in settlement discussions with the BPU Staff and theNew Jersey Division of Rate Counsel (New Jersey Rate Counsel) about the level of PSE&G's base transmission ROE; however, we cannot predict the outcome of these settlement 76 --------------------------------------------------------------------------------
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discussions. An adverse change to PSE&G's base transmission ROE or ROE incentives could be material. We estimate that for each 25 basis point reduction in PSE&G's base transmission ROE, and all other factors unchanged, PSE&G's annual Net Income and annual cash inflows would decrease by approximately$15 million . Wholesale Power Market Design InDecember 2019 ,FERC issued an order establishing new rules for PJM's capacity market, extending the PJM MOPR to include both new and existing resources that receive or are entitled to receive certain out-of-market payments, with certain exemptions.PSEG Power's New Jersey nuclear plants that receive ZEC payments will be subject to the new MOPR. In addition, as a result ofFERC's finding that default procurement auctions such as BGS could be considered subsidies, it is possible that other PSEG units could be subject to the MOPR. Resources that are subject to the MOPR continue to have the ability to justify a bid below the MOPR floor price under the unit-specific exemption. The MOPR floor prices are not expected to prevent either our nuclear units or gas-fired units from clearing in the next RPM auction. AFERC order issued inMay 2020 authorizing enhancements to the methodology used by PJM to price energy reserves has created additional uncertainty regarding the impact of the MOPR expansion in future RPM auctions onPSEG Power's nuclear units that receive ZECs. One of the findings made byFERC in that order will affect how the MOPR offer floors are calculated and could have the effect, in the future, of increasing the price floors for the plants and thereby increasing the risk of being unable to clear in an RPM auction. In addition, if one or more electric distribution zones inNew Jersey (or another state) were to become fixed resource requirement (FRR) service areas, procurements needed for that area could provide an alternate means for nuclear units whose ability to clear in RPM auctions was affected by the MOPR to provide capacity within PJM. We cannot predict whether additional changes will be made to the MOPR, or whether changes will occur in the PJM market that would impact our ability to clear any of these units in future RPM auctions. States that have clean energy programs designed to achieve public policy goals that support such resources as solar, offshore wind and nuclear, are not prevented from pursuing those programs by the expanded MOPR and could choose to utilize the existing FRR approach authorized under the PJM tariff. Subsidized units that cannot clear in a RPM capacity auction because of the expanded MOPR could still count as capacity resources to a load serving entity (LSE) using the FRR approach. In aMarch 2020 order, the BPU initiated an investigation to examine whetherNew Jersey can achieve its long-term clean energy and environmental objectives under the current resource adequacy procurement paradigm and potential alternatives. One of the areas of inquiry concerns the potential creation of FRR service areas withinNew Jersey . We cannot predict the impact these rules or any measures taken by the BPU will have on the capacity market or our generating stations. See Part II, Item 5. Other Information. InJanuary 2020 ,New Jersey rejoined the Regional Greenhouse Gas Initiative (RGGI). As a result, generating plants operating inNew Jersey , including those owned byPSEG Power , that emit CO2 emissions will be required to procure credits for each ton they emit. In response to RGGI, PJM initiated a process in 2019 to investigate the development of a carbon pricing mechanism that may mitigate the environmental and financial distortions that could occur when emissions "leak" from non-participating states to the RGGI states. If the process leads to a market solution, it could have a material impact on the value ofPSEG Power's generating fleet. 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 thePassaic and Hackensack Rivers are alleged by Federal and State agencies to have discharged substantial contamination into thePassaic 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. 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 InApril 2019 ,PSEG Power's Salem 1,Salem 2 andHope Creek nuclear plants were awarded ZECs by the BPU. Pursuant to a process established by the BPU, ZECs are purchased from selected nuclear plants and recovered through a non-bypassable distribution charge in the amount of$0.004 per kilowatt-hour used (which is equivalent to approximately$10 per megawatt hour generated in payments to selected nuclear plants (ZEC payment)). These nuclear plants are expected to receive ZEC revenue for approximately three years, throughMay 2022 , and will be obligated to maintain operations during that period, subject to exceptions specified in the ZEC legislation.PSEG Power has and will continue to recognize revenue monthly as the nuclear plants generate electricity and satisfy their performance obligations. The ZEC payment may be adjusted by the BPU (a) 77 --------------------------------------------------------------------------------
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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. For instance, theNew Jersey Rate Counsel, in written comments filed with the BPU, has advocated for the BPU to offset market benefits resulting fromNew Jersey's rejoining the RGGI from the ZEC payment. PSEG intends to vigorously defend against these arguments. Due to its preliminary nature, PSEG cannot predict the outcome of this matter. The BPU's decision awarding ZECs has been appealed by the New Jersey Rate Counsel. PSEG cannot predict the outcome of this matter. The BPU issued an order inMay 2020 outlining the process for applying for ZECs for the next three-year eligibility period starting inJune 2022 and is expected to issue a decision regarding any ZEC applications and any change in the amount of future ZEC payments byApril 2021 .PSEG Power is not aware of any changes that would materially affect its ability to establish eligibility to be awarded ZECs under the application requirements that resulted in the award of ZECs toSalem 1,Salem 2 andHope Creek inApril 2019 . However,PSEG Power cannot predict whether other plants besidesSalem 1,Salem 2 andHope Creek will apply for ZECs in the future. In the event that (i) the ZEC program is overturned or otherwise materially adversely modified through legal process, (ii) the terms and conditions of the subsequent period under the ZEC program, including the amount of ZEC payments that may be awarded, materially differ from those of the current ZEC period, or (iii) any of theSalem 1,Salem 2 andHope Creek plants is not awarded ZEC payments by the BPU and does not otherwise experience a material financial change,PSEG Power will take all necessary steps to retire all of these plants subsequent to the initial ZEC period at or prior to a scheduled refueling outage. Alternatively, if all of theSalem 1,Salem 2 andHope Creek plants are selected to continue to receive ZEC payments but the financial condition of the plants is materially adversely impacted by changes in commodity prices,FERC's changes to the capacity market construct (absent sufficient capacity revenues provided under a program approved by the BPU in accordance with aFERC -authorized capacity mechanism), or, in the case of theSalem nuclear plants, decisions by theEPA and state environmental regulators regarding the implementation of Section 316(b) of the Clean Water Act and related state regulations, or other factors,PSEG Power would still take all necessary steps to retire all of these plants. Retirement of these plants would result in a material adverse impact onPSEG's andPSEG Power's financial results. Nuclear Refueling Outage TheSalem 1 nuclear generating plant is expected to enter into a scheduled refueling outage inOctober 2020 . In light of the COVID-19 pandemic, we have implemented additional health protocols to protect the health and safety of our employees and contractors, including daily health screenings, increased hygiene, physical distancing, PPE requirements and close-contact monitoring. During this outage, the plant's main generator stator, which has reached the end of its useful life, is expected to be replaced. The process for replacingSalem 1's generator stator is highly complex. We also plan to perform additional reactor vessel inspections and upgrades. Limitations due to additional health protocols, delays in replacing the main generator stator due to its complexity, or adverse findings from the reactor vessel inspections could result in an extended outage and in turn, lower revenues and increased costs, which could have a material impact on the results of operations of the plant andPSEG Power . California Solar Facilities As part of its solar production portfolio,PSEG Power owns and operates twoCalifornia -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. InJanuary 2019 , PG&E and its parent company PG&E Corporation filed for Chapter 11 bankruptcy protection and inJune 2020 the bankruptcy judge approved PG&E's bankruptcy plan, which included the assumption ofPSEG Power's PPAs. Offshore Wind InJune 2019 , the BPU selected Ørsted US Offshore Wind'sOcean Wind project as the winning bid inNew Jersey's initial solicitation for 1,100 MW of offshore wind generation. InOctober 2019 , PSEG exercised its option on Ørsted'sOcean Wind project, resulting in a period of exclusive negotiation for PSEG to potentially acquire a 25% equity interest in the project, subject to negotiations toward a joint venture agreement, advanced due diligence and any required regulatory approvals. Additionally, PSEG and Ørsted each owns 50% ofGarden State Offshore Energy LLC (GSOE) which holds rights to an offshore wind lease area. PSEG and Ørsted are exploring other offshore wind opportunities through GSOE. Tax Legislation InJuly 2020 , theIRS issued final and proposed regulations addressing the limitation on deductible interest expense contained in the Tax Act. PSEG is in the process of analyzing these regulations, which may impact PSEG's,PSE&G's andPSEG Power's financial condition and cash flows. 78 --------------------------------------------------------------------------------
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InMarch 2020 , the federal Coronavirus Aid, Relief, and Economic Security Act (CARES Act) was enacted. We continue to assess the impact of the tax aspects of the CARES Act on our results of operations and cash flow. We expect that a prolonged coronavirus pandemic, the tax provisions of the CARES Act and any future coronavirus-related federal or state legislation could have a material impact on our effective tax rate and cash tax position. For non-regulated businesses, the Tax Act enacted rules that 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 2018 and 2019, the tax deductibility of a portion ofPSEG's andPSEG Power's interest was disallowed but is expected to be realized in future periods. However, certain aspects of the law are unclear. Therefore, we recorded taxes based on our interpretation of the relevant statute. The CARES Act favorably increased the limitation on the amount of interest that can deducted in 2019 and 2020. While this will not impact 2019, the increased limitation will allow a portion of the previously disallowed amounts to reducePSEG's andPSEG Power's 2020 taxable income. Amounts recorded under the Tax Act and the CARES Act, such as depreciation and interest disallowance, are subject to change based on several factors, including but not limited to, theIRS and state taxing authorities issuing additional guidance and/or further clarification. Any further guidance or clarification could impact PSEG's,PSE&G's andPSEG Power's financial statements. For additional information, see Item 1. Note 16. Income Taxes. InJuly 2018 ,New Jersey made changes to its income tax laws, including imposing a temporary surtax of 2.5% effectiveJanuary 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 underNew 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. There are certain aspects of the law that are not clear. We anticipateNew Jersey will be issuing clarifying guidance regarding combined reporting rules. Any further guidance or clarification could impactPSEG's andPSEG Power's financial statements. 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 our CEF program 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,
• advocate for the continuation of the ZEC program and measures to ensure
the implementation by PJM,
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, investors and suppliers, 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, the first quarter 2020 10-Q and in our Form 10-K, for 2020 and beyond, the key issues and challenges we expect our business to confront include: • regulatory and political uncertainty, both with regard to future energy
policy, design of energy and capacity markets, transmission policy and
environmental regulation, as well as with respect to the outcome of any
legal, regulatory or other proceedings,
• the continuing impact of the ongoing coronavirus pandemic and theassociated economic impact, which could extend beyond the duration of the
pandemic,
• the continuing impacts of the Tax and CARES Acts and future changes in
federal and 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,
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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
portions thereof or other existing businesses or the acquisition or
development of new businesses,
• the expansion of our geographic footprint, and
• investments in capital improvements and additions, including the
installation of environmental upgrades and retrofits, improvements tosystem resiliency, modernizing existing infrastructure and participation
in transmission projects through
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. RESULTS OF OPERATIONS PSEG Our results of operations are primarily comprised of the results of operations of our principal operating subsidiaries,PSE&G andPSEG 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/ Six Months Ended Increase/ June 30, (Decrease) June 30, (Decrease) 2020 2019 2020 vs. 2019
2020 2019 2020 vs. 2019
Millions Millions % Millions Millions %
Operating Revenues
Energy Costs 595 704 (109 ) (15 )
1,501 1,828 (327 ) (18 )
Operation and
Maintenance 733 750 (17 ) (2 ) 1,487 1,506 (19 ) (1 )
Depreciation and
Amortization 315 307 8 3 639 621 18 3 Loss on Asset Dispositions - 395 (395 ) N/A - 395 (395 ) N/A
Income from Equity
Method Investments 3 5 (2 ) (40 ) 6 7 (1 ) (14 )
on Trust Investments 201 39 162 N/A
(20 ) 167 (187 ) N/A
Other Income
(Deductions) 38 33 5 15 42 66 (24 ) (36 )
Net Non-Operating
Pension and OPEB
Credits (Costs) 62 33 29 88 124 66 58 88 Interest Expense 151 137 14 10 304 270 34 13
Income Tax (Benefit)
Expense 109 (20 ) 129 N/A 153 129 24 19
The following discussions for
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PSE&G
Three Months Ended Increase/ Six Months Ended Increase/
June 30, (Decrease) June 30, (Decrease)
2020 2019 2020 vs. 2019 2020 2019 2020 vs. 2019
Millions Millions % Millions Millions %
Operating Revenues $ 1,456 $ 1,382 $ 74 5 $ 3,339 $ 3,414 $ (75 ) (2 )
Energy Costs 510 529 (19 ) (4 ) 1,218 1,476 (258 ) (17 )
Operation and
Maintenance 380 369 11 3 766 777 (11 ) (1 )
Depreciation and
Amortization 217 202 15 7 439 414 25 6
Net Gains (Losses)
on Trust Investments 1 - 1 N/A 1 1 - -
Other Income
(Deductions) 26 19 7 37 53 38 15 39
Net Non-Operating
Pension and OPEB
Credits (Costs) 52 29 23 79 103 59 44 75
Interest Expense 98 89 9 10 194 176 18 10
Income Tax Expense
(Benefit) 47 14 33 N/A 156 39 117 N/A
Three Months Ended June 30, 2020 as Compared to 2019
Operating Revenues increased $74 million due to changes in delivery, commodity,
clause and other operating revenues.
Delivery Revenues increased $69 million due primarily to
• Transmission revenues were $66 million higher due to increased 2020
revenue requirements attributable to higher rate base investment and the
prior year flowback of certain excess deferred taxes that ended at
year-end 2019.
• Gas distribution revenues increased by
million increase due to higher volumes and a
GSMP I and GSMP II, partially offset by a
Normalization Charges (WNCs).
• Electric distribution revenues increased by
increase due to higher volumes, partially offset by a
in the collection of Green Program Recovery Charges (GPRC).
• Gas and Electric revenues decreased by
the flowback to customers of excess deferred tax liabilities and tax
repair-related accumulated deferred income tax benefits resulting from
rate reductions, which is offset in Income Tax Expense.
Commodity Revenues decreased $34 million as a result of lower Electric revenues,
partially offset by higher Gas revenues. The changes in Commodity revenues for
both electric and gas are entirely offset by the changes in Energy Costs. PSE&G
earns no margin on the provision of BGS or basic gas supply service (BGSS) to
retail customers.
• Electric commodity revenues decreased $60 million due primarily to $67 million in lower BGS prices, partially offset by
sales volumes.
• Gas commodity revenues increased
higher BGSS sales volumes, partially offset by a
prices.
Clause Revenues increased$23 million due primarily to a$15 million reduction in Tax Adjustment Credit (TAC) deferrals and higher SBC revenues of$9 million . The changes in the TAC deferral and SBC amounts are entirely offset by changes in the amortization of Regulatory Assets and Regulatory Liabilities and related costs in O&M, D&A, Interest and Income Tax Expenses. PSE&G does not earn margin on TAC deferrals or SBC revenues. Other Operating Revenues increased by$16 million due primarily to an$11 million increase in solar renewable energy credit (SREC) revenues and$4 million in higher ZEC revenues billed sincemid-April 2019 . See Item 1. Note 11. Commitments and Contingent Liabilities. The changes in these components of revenues are entirely offset by changes to Energy Costs. 81 --------------------------------------------------------------------------------
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Operating Expenses Energy Costs decreased$19 million . This is entirely offset by changes in Commodity Revenues and Other Operating Revenues. Operation and Maintenance increased$11 million due primarily to$10 million in COVID-19 related costs, an$8 million increase in gas bad debt expense and a net$3 million increase in clause and renewable-related expenditures. These increases were partially offset by a$6 million decrease in appliance service costs, a$2 million decrease in distribution corrective and preventative expenditures and a$2 million decrease in transmission-related expenditures. Depreciation and Amortization increased$15 million due primarily to an$11 million increase related to additional plant in service and a$3 million increase in the amortization of Regulatory Assets. Other Income (Deductions) increased$7 million due primarily to an increase in the allowance for funds used during construction (AFUDC). Net Non-Operating Pension and OPEB Credits (Costs) increased$23 million due primarily to a$12 million increase in the expected return on plan assets, a$9 million decrease in interest cost and a$3 million decrease in the amortization of the net actuarial loss, partially offset by a$1 million decrease in the amortization of prior service credit. Interest Expense increased$9 million due primarily to a$6 million increase from debt issuances in January andMay 2020 and a$4 million increase from net debt issuances in May andAugust 2019 . Income Tax Expense increased$33 million due primarily to higher pre-tax income and an increase in bad debt flow-through. Six Months EndedJune 30, 2020 as Compared to 2019 Operating Revenues decreased$75 million due to changes in delivery, commodity, clause and other operating revenues. Delivery Revenues increased$159 million due primarily to • Transmission revenues were$139 million higher due to increased 2020 revenue requirements attributable to higher rate base investment and the prior year flowback of certain excess deferred taxes that ended at year-end 2019. • Gas distribution revenues increased$26 million due primarily to a$36 million increase in WNCs and an$18 million increase from the GSMP I and
GSMP II. These increases were partially offset by a
due to lower volumes and a
• Electric distribution revenues decreased
million decrease attributable to lower sales volumes, partially offset by
a $3 million increase in GPRC collections.
• Electric and Gas revenues further decreased by $2 million due to a netincrease in the flowback to customers of excess deferred tax liabilities
and tax repair-related accumulated deferred income tax benefits resulting
from rate reductions, which is offset in Income Tax Expense.
Commodity Revenues decreased$326 million as a result of lower 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 BGSS and BGS to retail customers. • Electric commodity revenues decreased$190 million due primarily to$156
million in lower BGS prices and
• Gas commodity revenues decreased
prices of
Clause Revenues increased$25 million due primarily to a$25 million increase in TAC deferrals and higher SBC revenues of$6 million . These increases were partially offset by a$7 million decrease in Margin Adjustment Clause (MAC) revenues. The changes in TAC deferral amounts, SBC and MAC revenues are entirely offset by changes in the amortization of Regulatory Assets and Regulatory Liabilities and related costs in O&M, D&A, Interest and Income Tax Expenses. PSE&G does not earn margin on TAC deferrals, SBC and MAC revenues. Other Operating Revenues increased by$67 million due primarily to$42 million in ZEC revenues billed sincemid-April 2019 and a$25 million increase in SREC revenues. See Item 1. Note 11. Commitments and Contingent Liabilities. The changes in these components of revenues are entirely offset by changes to Energy Costs. Operating Expenses Energy Costs decreased$258 million . This is entirely offset by changes in Commodity Revenues and Other Operating Revenues. 82 --------------------------------------------------------------------------------
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Operation and Maintenance decreased$11 million due primarily to a net$10 million decrease in clause and renewable-related expenditures, an$8 million decrease in appliance service costs, a$5 million decrease in distribution corrective and preventative maintenance expenditures, a$4 million decrease in injuries and damages, a$4 million decrease in transmission-related expenditures and a$3 million reduction in other operating expenses. These decreases were partially offset by$12 million of COVID-19 related costs and an$11 million increase in gas bad debt expense. Depreciation and Amortization increased$25 million due primarily to a$22 million increase related to additional plant in service and a$2 million increase in the amortization of Regulatory Assets. Other Income (Deductions) increased$15 million due primarily to an increase in AFUDC. Net Non-Operating Pension and OPEB Credits (Costs) increased$44 million due primarily to a$23 million increase in the expected return on plan assets, a$17 million decrease in interest cost and a$7 million decrease in the amortization of the net actuarial loss, partially offset by a$3 million decrease in the amortization of prior service credit. Interest Expense increased$18 million due primarily to a$12 million increase from net debt issuances in May andAugust 2019 and a$10 million increase from debt issuances in January andMay 2020 . These increases were partially offset by a decrease of$3 million due to a reduction in short-term borrowings. Income Tax Expense increased$117 million due primarily to higher pre-tax income and the reduction in the 2020 flowback of PSE&G's excess deferred income tax liabilities, as PSE&G refunded allFERC -approved, transmission-related excess deferred income taxes that are not subject to the normalization rules in 2019.PSEG Power Three Months Ended Increase/ Six Months Ended Increase/ June 30, (Decrease) June 30, (Decrease) 2020 2019 2020 vs. 2019 2020 2019 2020 vs. 2019 Millions Millions % Millions Millions % Operating Revenues$ 683 $ 1,083 $ (400 ) (37 )$ 1,903 $ 2,499 $ (596 ) (24 ) Energy Costs 323 411 (88 ) (21 ) 999 1,197 (198 ) (17 ) Operation and Maintenance 225 268 (43 ) (16 ) 466 503 (37 ) (7 ) Depreciation and Amortization 91 95 (4 ) (4 ) 185 189 (4 ) (2 ) Loss on Asset Dispositions - 395 (395 ) N/A - 395 (395 ) N/A Income from Equity Method Investments 3 5 (2 ) (40 ) 6 7 (1 ) (14 )Net Gains (Losses) on Trust Investments 196 38 158 N/A (24 ) 164 (188 ) N/A Other Income (Deductions) 12 15 (3 ) (20 ) (11 ) 28 (39 ) N/A Net Non-Operating Pension and OPEB Credits (Costs) 9 3 6 N/A 17 6 11 N/A Interest Expense 30 26 4 15 64 51 13 25 Income Tax Expense (Benefit) 64 (11 ) 75 N/A (6 ) 113 (119 ) N/A Three Months EndedJune 30, 2020 as Compared to 2019 Operating Revenues decreased$400 million due primarily to changes in generation and gas supply revenues. Generation Revenues decreased$435 million due primarily to • a net decrease of$403 million due to MTM losses in 2020 as compared to
MTM gains in 2019. Of this amount, there was a
to changes in forward prices this year as compared to last year coupled
with a
to realized upon settlement,
• a net decrease of $30 million in capacity revenues due primarily to
decreases in auction prices in the PJM region, and
• a decrease of
primarily due to lower volumes coupled with lower prices,
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• partially offset by an increase of$16 million in ZEC revenue due to increased generation at theSalem nuclear generating station.
Gas Supply Revenues increased
• a net increase of
million due to lower average sales prices.
Operating Expenses Energy Costs represent the cost of generation, which includes fuel costs for generation as well as purchased energy in the market, and gas purchases to meetPSEG Power's obligation under its BGSS contract with PSE&G. Energy Costs decreased$88 million due to Generation costs decreased$113 million due primarily to • a net decrease of$86 million due to MTM gains in 2020 as compared to MTM
losses in 2019. Of this amount, there was a
changes in forward prices this year as compared to last year coupled with
a
realized upon settlement,
• a net decrease of
the PJM region primarily due to the sale of our ownership interests in
Keystone and Conemaugh generation plants coupled with lower volumes of gas
in the PJM region. This was partially offset by utilization of higher
volumes of gas in the
commercial operations of Bridgeport Harbor Station Unit 5 (BH5) in June
2019 , and
• a decrease of
(LOCOM) adjustment on oil inventory due to the recovery in oil prices.
Gas costs increased
$26 million was due to higher volumes sold, partially offset by$13 million due to a decrease in the average cost of gas, and
• a net increase of
which
offset by
Operation and Maintenance decreased$43 million due primarily to a$34 million net decrease at our fossil plants due to the sale of our ownership interests in the Keystone and Conemaugh generation plants and lower planned outage costs in 2020. In addition, there was an$8 million net decrease due to lower outage costs at our nuclear plants. Depreciation and Amortization decreased$4 million due primarily to a$3 million net decrease at our nuclear plants due to the Peach Bottom License Renewal that was approved by the NRC inMarch 2020 , partially offset by an increased asset base. This decrease was coupled with a$2 million net decrease at our fossil plants, primarily due to the sale of our ownership interests in the Keystone and Conemaugh generation plants in 2019, partially offset by an increase due to BH5 being placed into service inJune 2019 . Loss on Asset Dispositions of$395 million in 2019 was due to an asset impairment related to the sale ofPSEG Power's interests in the Keystone and Conemaugh fossil generation plants (see Item 1. Note 4. Early Plant Retirements/Asset Dispositions).Net Gains (Losses) on Trust Investments increased$158 million due primarily to a$149 million increase resulting from net unrealized gains on equity investments in theNDT Fund and a$7 million increase in net realized gains onNDT Fund investments. Net Non-Operating Pension and OPEB Credits (Costs) increased$6 million due to a$3 million decrease in interest cost, a$2 million increase in the expected return on plan assets, and a$1 million decrease in the amortization of the net actuarial loss. Interest Expense increased$4 million due primarily to lower capitalized interest as a result of BH5 being place into service in 2019, partially offset by anApril 2020 debt maturity. Income Tax Expense increased$75 million due primarily to higher pre-tax income, including higher pre-tax income from the NDT qualified fund, which is subject to an additional trust tax, partially offset by the tax benefit from changes in uncertain tax positions as a result of the settlement of the 2011-2016 federal income tax audits. 84 --------------------------------------------------------------------------------
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Six Months EndedJune 30, 2020 as Compared to 2019 Operating Revenues decreased$596 million due primarily to changes in generation and gas supply revenues. Generation Revenues decreased$500 million due primarily to • a net decrease of$336 million due to lower MTM gains in 2020 as compared
to 2019. Of this amount, there was a
in forward prices this year as compared to last year coupled with a $118
million decrease due to losses on positions reclassified to realized upon
settlement in 2020 compared to gains in 2019,
• a net decrease of
prices in PJM, NE and
sold in the PJM region primarily due to the sale of our ownership
interests in Keystone and Conemaugh generation plants. This was partially
offset by higher volumes of electricity sold in the NE region, primarily
due to the commencement of commercial operations of BH5 in June 2019 ,
• a net decrease of $65 million in capacity revenues due primarily to
decreases in auction prices in the PJM region, partially offset by the
commencement of commercial operations of BH5 in June 2019 in the NE
region, and
• a decrease of
primarily due to lower volumes coupled with lower prices,
• partially offset by an increase of
started in
Gas Supply Revenues decreased
million was due to a decrease in sales volumes and
lower average sales prices,
• partially offset by a net increase of
parties, of which
offset by
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 meetPSEG Power's obligation under its BGSS contract with PSE&G. Energy Costs decreased$198 million due to Generation costs decreased$123 million due primarily to • a net decrease of$106 million in fuel costs reflecting lower gas prices
in the PJM and NY regions coupled with the utilization of lower volumes of
coal in the PJM region primarily due to the sale of our ownership
interests in the Keystone and Conemaugh generation plants, and lower
volumes of gas used in the PJM region. This was partially offset by
utilization of higher volumes of gas in the NE region at higher prices due
to the commencement of commercial operations at BH5 in June 2019 , and
• a net decrease of
to 2019 resulting from changes in forward prices this year as compared to
last year,
• partially offset by an
on oil inventory caused by a decrease in oil demand and pricing earlier in
2020.
Gas costs decreased
which
to a decrease in the average cost of gas,
• partially offset by a net increase of $11 million related to sales to
third parties, of which $53 million was due to higher volumes sold,
partially offset by
gas.
Operation and Maintenance decreased$37 million due primarily to a net decrease at our fossil plants, due to the sale of our ownership interests in the Keystone and Conemaugh generation plants in 2019, coupled with lower planned outage costs in 2020. Depreciation and Amortization decreased$4 million due primarily to a$3 million net decrease at our nuclear plants due to the Peach Bottom License Renewal that was approved by the NRC inMarch 2020 , partially offset by an increased asset base. This decrease was coupled with a$2 million net decrease at our fossil plants, primarily due to the sale of our ownership interests in the Keystone and Conemaugh generation plants in 2019, partially offset by an increase due to BH5 being placed into service inJune 2019 . 85 --------------------------------------------------------------------------------
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Loss on Asset Dispositions of$395 million in 2019 was due to an asset impairment related to the sale ofPSEG Power's interests in the Keystone and Conemaugh fossil generation plants (see Item 1. Note 4. Early Plant Retirements/Asset Dispositions).Net Gains (Losses) on Trust Investments decreased$188 million due primarily to a$171 million decrease resulting from net unrealized losses in 2020 as compared to net unrealized gains in 2019 on equity investments in theNDT Fund and a$15 million decrease in net realized gains onNDT Fund investments. Other Income (Deductions) decreased$39 million primarily due to purchases of net operating losses (NOLs) in 2020 underNew Jersey's Technology Tax Benefit Transfer Program. Net Non-Operating Pension and OPEB Credits (Costs) increased$11 million due to a$5 million increase in the expected return on plan assets, a$5 million decrease in interest cost and a$2 million decrease in the amortization of the net actuarial loss, partially offset by a$1 million decrease in the amortization of prior service credit. Interest Expense increased$13 million due primarily to lower capitalized interest as a result of BH5 being place into service in 2019, partially offset by anApril 2020 debt maturity. Income Tax Expense decreased$119 million due primarily to lower pre-tax income, including lower pre-tax income from the NDT qualified fund, which is subject to an additional trust tax, the benefit from the 2019 NOLs purchased under the New Jersey Technology Tax Benefit Transfer Program in 2020, and the tax benefit from changes in uncertain tax positions as a result of the settlement of the 2011-2016 federal income tax audits. LIQUIDITY AND CAPITAL RESOURCES The following discussion of our liquidity and capital resources is on a consolidated basis, noting the uses and contributions, where material, of our two direct major operating subsidiaries. Operating Cash Flows We continue to expect our operating cash flows combined with cash on hand and financing activities to be sufficient to fund planned capital expenditures and provide opportunities for shareholder dividends. For the six months endedJune 30, 2020 , our operating cash flow decreased$160 million as compared to the same period in 2019. The net decrease was primarily due to the net changes from our subsidiaries, as discussed below, and lower net tax payments in 2020 at the parent company andEnergy Holdings . Given the current economic challenges, PSE&G has informed both our residential customers and state regulators that all non-safety related service disconnections for non-payment will be temporarily suspended. In addition, the current economic conditions have adversely impacted residential and C&I customer payment patterns. While the negative impact on customer payment patterns, including a significant decrease in cash inflow and higher Accounts Receivable aging and associated increasing bad debt expense did not have a material impact on our cash flows for the six months endedJune 30, 2020 , we expect a prolonged adverse change to customer payment patterns could materially and adversely impact our cash flows from operations beyond the duration of the coronavirus pandemic. PSE&G PSE&G's operating cash flow increased$161 million from$838 million to$999 million for the six months endedJune 30, 2020 , as compared to the same period in 2019, due primarily to higher earnings in 2020, and$136 million in decreased payments due to lower BGS payments from decreased sales. These increases were partially offset by tax payments in 2020 as compared to tax refunds in 2019 and a decrease of$154 million from increased regulatory deferrals including BGS due to lower sales, a Weather Normalization deferral resulting from a warmer than normal winter, and the Tax Adjustment Credit.PSEG Power PSEG Power's operating cash flow decreased$524 million from$1,150 million to$626 million for the six months endedJune 30, 2020 , as compared to the same period in 2019, due to a$360 million reduction related to counterparty cash collateral posting requirements, lower earnings, a$63 million decrease from net collections of counterparty receivables, a$20 million decrease in the usage of fuels, materials and supplies, and tax payments in 2020 as compared to tax refunds in 2019. Short-Term Liquidity PSEG meets its short-term liquidity requirements, as well as those ofPSEG Power , primarily through the issuance of commercial paper and, from time to time, short-term loans. PSE&G maintains its own separate commercial paper program to meet its short-term liquidity requirements. Each commercial paper program is fully back-stopped by its own separate credit facilities. 86 --------------------------------------------------------------------------------
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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. InMarch 2020 , PSEG entered into a$300 million , 364-day term loan agreement and inApril 2020 it entered into two 364-day term loan agreements for$200 million and$300 million . These term loans provide an additional source of liquidity for our operations as we continue to monitor the impact of the ongoing coronavirus pandemic on the volatility and availability of the capital and commercial paper markets. These term loans are not included in the credit facility amounts presented in the following table. Our total credit facilities and available liquidity as ofJune 30, 2020 were as follows: As of June 30, 2020 Total Available Company/Facility Facility Usage Liquidity Millions PSEG$ 1,500 $ 408 $ 1,092 PSE&G 600 17 583 PSEG Power 2,100 136 1,964 Total$ 4,200 $ 561 $ 3,639 As ofJune 30, 2020 , our credit facility capacity was in excess of our projected maximum liquidity requirements over our 12 month planning horizon as we continue to monitor the impact and volatility of the ongoing coronavirus pandemic on cash flows and capital market conditions. Our maximum liquidity requirements are based on stress scenarios that incorporate changes in commodity prices and the potential impact ofPSEG 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 event of a deterioration ofPSEG Power's credit rating, certain ofPSEG 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 ifPSEG Power were to lose its investment grade credit rating was approximately$845 million and$974 million as ofJune 30, 2020 andDecember 31, 2019 , respectively. For additional information, see Item 1. Note 12. Debt and Credit Facilities. Long-Term Debt Financing During the next twelve months, • PSEG has a$700 million floating rate term loan maturing inNovember 2020 , • PSE&G has$250 million of 3.50% Medium-Term Notes (MTN), Series G, maturing inAugust 2020 ,$9 million of 7.04% MTN, Series A, maturing in
and
and
•
PSEG,PSEG Power ,Energy Holdings , PSEG LI and Services participate in a corporate money pool, an aggregation of daily cash balances designed to efficiently manage their respective short-term liquidity needs, which are accounted for as intercompany loans. InApril 2020 , PSEG utilized external sources of liquidity, including the commercial paper markets and term loans, to repay a loan toPSEG Power through the money pool andPSEG Power used the proceeds from this loan repayment to redeem its$406 million of 5.13% Senior Notes at maturity. For additional information see Item 1. Note 12. Debt and Credit Facilities. Guarantor Financial InformationPSEG Power's Senior Notes are fully and unconditionally guaranteed on a joint and several basis by its subsidiaries,PSEG Fossil LLC ,PSEG Nuclear LLC andPSEG Energy Resources & Trade LLC . Each guarantor subsidiary is a wholly owned consolidated subsidiary ofPSEG Power . Summarized financial information is being presented, on a combined basis, only forPSEG Power (parent company) and the guarantors ofPSEG Power's Senior Notes, excluding investments in, and earnings (losses) from, subsidiaries that are not guarantors. All transactions betweenPSEG Power (parent company) and the guarantor subsidiaries are eliminated in the combined summarized financial information. The required disclosures for the year-to-date interim period and the most recent 87 --------------------------------------------------------------------------------
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fiscal year have been moved outside the Notes to Condensed Consolidated Financial Statements and are provided in the following tables.
Six Months Ended Year Ended
June 30, 2020 December 31, 2019
Millions
Operating Revenues (A) $ 1,867 $ 4,315
Operating Income $ 250 $ 451
Net Income $ 191 $ 484
(A) Operating Revenues include sales to affiliates of
million, respectively for the six months ended June 30, 2020 and year
ended December 31, 2019 , respectively.
As of As of
June 30, 2020 December 31, 2019 Millions
Current Receivables from Subsidiaries and Affiliates $ 2,274 $ 2,456 Total Current Assets $ 3,289 $ 3,559 Noncurrent Receivables from Affiliates $ 28 $ 17 Total Noncurrent Assets $ 7,056 $ 7,025 Current Payables to Subsidiaries and Affiliates $ 249 $ 218 Total Current Liabilities $ 1,373 $ 1,155 Noncurrent Payables to Affiliates $ 53 $ 115 Total Noncurrent Liabilities $ 4,274 $ 4,934 Pension and NDT Fund ObligationsIRS minimum funding requirements for pension plans are determined based on the fund assets and liabilities at the end of a calendar year for the subsequent calendar year. As a result, the market downturn associated with the ongoing coronavirus pandemic is not expected to impact our pension contributions in 2020. In the event of a prolonged economic downturn associated with the ongoing coronavirus pandemic, our contributions to the pension plans may increase in future periods to meetIRS minimum funding requirements. PSEG had accumulated funding credits totaling approximately$600 million through 2019, which represent historical contributions in excess ofIRS minimum funding requirements, and these credits can be applied to offset any future cash contribution obligations. In addition, the NRC requires a biennial filing of the NDT fund balances against the decommissioning liability estimate. Any funding shortfalls are required to be cured prior to the next NRC reporting period. The market downturn associated with the ongoing coronavirus pandemic is not currently expected to result in any supplemental required funding of theNDT Fund . To the extent of a prolonged economic downturn associated with the ongoing coronavirus pandemic, our funding requirements may increase in future periods to meet NRC minimum funding requirements. Common Stock Dividends OnJuly 21, 2020 , our Board of Directors declared a$0.49 dividend per share of common stock for the third quarter of 2020. This reflects an indicative annual dividend rate of$1.96 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, the impact of the ongoing coronavirus pandemic on our business and the capital and credit markets and other factors that the Board of Directors deems relevant. For additional information related to cash dividends on our common stock, see Item 1. Note 18. Earnings Per Share (EPS) and Dividends. Credit Ratings If the rating agencies lower or withdraw our credit ratings, such revisions may adversely affect the market price of our securities and serve to materially increase our cost of capital and limit access to capital. Credit Ratings shown are for securities that we typically issue. Outlooks are shown for Issuer Credit Ratings (Moody's) and Corporate Credit Ratings (S&P) and can 88 --------------------------------------------------------------------------------
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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.
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
PSEG Power
Outlook Stable Stable
Senior Notes Baa1 BBB+
(A) Moody's ratings range from Aaa (highest) to C (lowest) for
long-term securities and P1 (highest) to NP (lowest) for short-term
securities.
(B) S&P ratings range from AAA (highest) to D (lowest) for long-term
securities and A1 (highest) to D (lowest) for short-term
securities.
CAPITAL REQUIREMENTS
We expect that all of our capital requirements over the next three years will
come from a combination of internally generated funds and external debt
financing. There were no material changes to our projected capital expenditures
as compared to amounts disclosed in our Form 10-K. See Executive Overview of
2020 and Future Outlook for additional information.
PSE&G
During the six months ended June 30, 2020 , PSE&G made capital expenditures of
$1,190 million , primarily for T&D system reliability. This does not include
expenditures for cost of removal, net of salvage, of $44 million , which are
included in operating cash flows.
PSEG Power
During the six months ended June 30, 2020 , PSEG Power made capital expenditures
of $114 million , excluding $104 million for nuclear fuel, primarily related to
various nuclear and solar projects.
ACCOUNTING MATTERS
For information related to recent accounting matters, see Item 1. Note 2. Recent
Accounting Standards.
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