UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549
FORM 10-Q
(Mark One)
[ X ] QUARTERLY REPORT PURSUANT TO SECTION 13 OR
15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2001
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR
15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission Registrant, State of Incorporation, I.R.S. Employer
File Number Address, and Telephone Number Identification No.
- - ----------- ---------------------------------------------- -------------------
001-09120 PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED 22-2625848
(A New Jersey Corporation)
80 Park Plaza
P.O. Box 1171
Newark, New Jersey 07101-1171
973-430-7000
http://www.pseg.com
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes X No
As of April 30, 2001, Public Service Enterprise Group Incorporated had
outstanding 207,971,318 shares of its sole class of Common Stock, without par
value.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
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TABLE OF CONTENTS
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements 1
Item 2. Management's Discussion and Analysis of Financial 18
Condition and Results of Operations
Item 3. Qualitative and Quantitative Disclosures About Market Risk 26
PART II. OTHER INFORMATION
Item 1. Legal Proceedings 27
Item 4. Submission of Matters to a Vote of Security Holders 27
Item 5. Other Information 28
Item 6. Exhibits and Reports on Form 8-K 28
Signature 29
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
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PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONSOLIDATED STATEMENTS OF INCOME
(Millions of Dollars, except for Per Share Data)
(Unaudited)
For the Quarters Ended
March 31,
-------------------------------------
2001 2000
-------------- ----------------
OPERATING REVENUES
Generation 561 530
Electric Transmission and Distribution 364 374
Gas Distribution 1,082 747
Trading 587 614
Other 220 218
-------------- ----------------
Total Operating Revenues 2,814 2,483
-------------- ----------------
OPERATING EXPENSES
Energy Costs 756 782
Gas Costs 787 480
Operation and Maintenance 538 478
Depreciation and Amortization 108 90
Taxes Other Than Income Taxes 48 50
-------------- ----------------
Total Operating Expenses 2,237 1,880
-------------- ----------------
OPERATING INCOME 577 603
Other Income and Deductions 13 11
Interest Expense (159) (137)
Preferred Securities Dividend Requirements
and Premium on Redemption (24) (24)
-------------- ----------------
INCOME BEFORE INCOME TAXES, EXTRAORDINARY ITEM AND
CUMULATIVE EFFECT OF A CHANGE IN ACCOUNTING PRINCIPLE 407 453
Income Taxes (153) (183)
-------------- ----------------
INCOME BEFORE EXTRAORDINARY ITEM
AND CUMULATIVE EFFECT OF A CHANGE IN
ACCOUNTING PRINCIPLE 254 270
Extraordinary Loss on Early Retirement of Debt (net of tax) (2) --
Cumulative Effect of a Change in Accounting Principle (net of 9 --
tax)
-------------- ----------------
NET INCOME $ 261 $ 270
============== ================
WEIGHTED AVERAGE COMMON
SHARES OUTSTANDING (000's) 208,390 216,437
============== ================
EARNINGS PER SHARE (BASIC AND DILUTED):
INCOME BEFORE EXTRAORDINARY ITEM $ 1.22 $ 1.25
AND CUMULATIVE EFFECT OF A CHANGE IN
ACCOUNTING PRINCIPLE
Extraordinary Loss on Early Retirement of Debt (net of tax) (0.01) --
Cumulative Effect of a Change in Accounting Principle (net of 0.04 --
tax)
-------------- ----------------
NET INCOME $ 1.25 $ 1.25
============== ================
DIVIDENDS PAID PER SHARE OF COMMON STOCK $ 0.54 $ 0.54
============== ================
See Notes to Consolidated Financial Statements.
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONSOLIDATED BALANCE SHEETS
ASSETS
(Millions of Dollars)
(Unaudited)
March 31, December 31,
2001 2000
------------------- -------------------
CURRENT ASSETS
Cash and Cash Equivalents $ 183 $ 102
Restricted Cash 15 --
Accounts Receivable:
Customer Accounts Receivable 975 778
Other Accounts Receivable 315 431
Allowance for Doubtful Accounts (55) (44)
Unbilled Revenues 245 357
Fuel 257 431
Materials and Supplies, net of valuation reserves-- 2001 and 2000, 167 155
$11
Prepayments 36 31
Energy Trading Contract 272 799
Other 33 99
------------------- -------------------
Total Current Assets 2,443 3,139
------------------- -------------------
PROPERTY, PLANT AND EQUIPMENT
Generation 3,111 2,699
Transmission and Distribution 8,497 8,479
Other 938 790
------------------- -------------------
Total 12,546 11,968
Accumulated Depreciation and Amortization (4,478) (4,266)
------------------- -------------------
Net Property, Plant and Equipment 8,068 7,702
------------------- -------------------
NONCURRENT ASSETS
Regulatory Assets 5,238 4,995
Long-Term Investments, net of accumulated amortization and
Valuation allowances-- 2001, $25; 2000, $72 4,721 4,545
Nuclear Decommissioning Fund 743 716
Other Special Funds 109 122
Other, net of accumulated amortization-- 2001 and 2000, $19 372 307
------------------- -------------------
Total Noncurrent Assets 11,183 10,685
------------------- -------------------
TOTAL ASSETS $ 21,694 $ 21,526
=================== ===================
See Notes to Consolidated Financial Statements.
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND CAPITALIZATION
(Millions of Dollars)
(Unaudited)
March 31, December 31,
2001 2000
------------------- -------------------
CURRENT LIABILITIES
Long-Term Debt Due Within One Year $ 653 $ 667
Commercial Paper and Loans 553 2,885
Accounts Payable 796 1,001
Accrued Taxes 194 24
Energy Trading Contracts 238 730
Other 523 405
------------------- -------------------
Total Current Liabilities 2,957 5,712
------------------- -------------------
NONCURRENT LIABILITIES
Deferred Income Taxes and ITC 3,124 3,107
Regulatory Liabilities 412 470
Nuclear Decommissioning 743 716
OPEB Costs 460 448
Cost of Removal 157 157
Other 456 415
------------------- -------------------
Total Noncurrent Liabilities 5,352 5,313
------------------- -------------------
COMMITMENTS AND CONTINGENT LIABILITIES -- --
------------------- -------------------
CAPITALIZATION
LONG-TERM DEBT
Long-Term Debt 5,828 5,297
Subsidiary's Securitization Debt 2,466 --
------------------- -------------------
Total Long-Term Debt 8,294 5,297
SUBSIDIARIES' PREFERRED SECURITIES
Preferred Stock Without Mandatory Redemption 80 95
Preferred Stock With Mandatory Redemption -- 75
Guaranteed Preferred Beneficial Interest in Subordinated 888 1,038
Debentures
------------------- -------------------
Total Subsidiaries' Preferred Securities 968 1,208
------------------- -------------------
COMMON STOCKHOLDERS' EQUITY
Common Stock, issued: 231,957,608 shares 3,603 3,604
Treasury Stock, at cost: 2001 and 2000--23,986,290 shares (895) (895)
Retained Earnings 1,641 1,493
Accumulated Other Comprehensive Loss (226) (206)
------------------- -------------------
Total Common Stockholders' Equity 4,123 3,996
------------------- -------------------
Total Capitalization 13,385 10,501
------------------- -------------------
TOTAL LIABILITIES AND CAPITALIZATION $ 21,694 $ 21,526
=================== ===================
See Notes to Consolidated Financial Statements.
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Millions of Dollars)
(Unaudited)
For the Quarters Ended
March 31,
----------------------------------------
2001 2000
----------------- -----------------
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 261 $ 270
Adjustments to reconcile net income to net cash flows from operating
activities:
Depreciation and Amortization 108 90
Amortization of Nuclear Fuel 27 26
Recovery of Electric Energy and Gas Costs-- net (80) 16
Provision for Deferred Income Taxes and ITC-- net (15) 29
Investment Distributions 86 12
Equity Income from Partnerships (25) (11)
Unrealized Gains on Investments (37) (31)
Leasing Activities 2 (18)
Net Changes in Certain Current Assets and Liabilities:
Restricted Cash (15) --
Accounts Receivable and Unbilled Revenues 42 (105)
Inventory-Fuel and Materials and Supplies 162 137
Prepayments (5) 24
Accounts Payable (205) 64
Accrued Taxes 172 185
Other Current Assets and Liabilities 217 44
Other (72) 35
----------------- -----------------
Net Cash Provided By Operating Activities 623 767
----------------- -----------------
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to Property, Plant and Equipment, excluding IDC and AFDC (356) (149)
Net Change in Long-Term Investments (58) (62)
Other -- (8)
----------------- -----------------
Net Cash Used in Investing Activities (414) (219)
----------------- -----------------
CASH FLOWS FROM FINANCING ACTIVITIES
Net Change in Short-Term Debt (2,332) (770)
Issuance of Long-Term Debt 3,088 300
Deferred Issuance Costs (200) --
Redemption/Purchase of Long-Term Debt (330) (99)
Redemption of Preferred Securities (240) --
Purchase of Treasury Stock -- --
Cash Dividends Paid on Common Stock (112) (117)
Other (2) --
----------------- -----------------
Net Cash Provided By (Used In) Financing Activities (128) (686)
----------------- -----------------
Net Change in Cash and Cash Equivalents 81 (138)
Cash and Cash Equivalents at Beginning of Period 102 259
----------------- -----------------
Cash and Cash Equivalents at End of Period $ 183 $ 121
================= =================
Income Taxes Paid $ 8 $ 1
Interest Paid $ 108 $ 96
See Notes to Consolidated Financial Statements.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Organization and Basis of Presentation
Organization
Public Service Enterprise Group Incorporated (PSEG) is an exempt public
utility holding company which has four principal direct wholly-owned
subsidiaries: Public Service Electric and Gas Company (PSE&G), PSEG Power LLC
(Power), PSEG Energy Holdings Inc. (Energy Holdings) and PSEG Services
Corporation (Services).
Basis of Presentation
The financial statements included herein have been prepared pursuant to the
rules and regulations of the Securities and Exchange Commission (SEC). Certain
information and note disclosures normally included in financial statements
prepared in accordance with generally accepted accounting principles have been
condensed or omitted pursuant to such rules and regulations. However, in the
opinion of management, the disclosures are adequate to make the information
presented not misleading. These consolidated financial statements and Notes to
Consolidated Financial Statements (Notes) should be read in conjunction with the
Notes contained in PSEG's 2000 Annual Report on Form 10-K. These Notes update
and supplement matters discussed in PSEG's 2000 Annual Report on Form 10-K.
The unaudited financial information furnished reflects all adjustments
which are, in the opinion of management, necessary to fairly state the results
for the interim periods presented. The year-end consolidated balance sheets were
derived from the audited consolidated financial statements included in PSEG's
2000 Annual Report on Form 10-K. Certain reclassifications of prior period data
have been made to conform with the current presentation.
Note 2. Accounting Matters
In July 2000, the Emerging Issues Task Force (EITF) 99-19, "Reporting
Revenue Gross as a Principal versus Net as an Agent" (EITF 99-19), provided
guidance on the issue of whether a company should report revenue based on the
gross amount billed to the customer or the net amount retained. The guidance
states that whether a company should recognize revenue based on the gross amount
billed or the net retained requires significant judgment, which depends on the
relevant facts and circumstances. In the first quarter of 2001, based on the
analysis and interpretation of EITF 99-19, PSEG reported all the revenues and
cost of goods sold on a gross basis for the energy related transactions. The
prior year financial statements for PSEG and its subsidiaries have been restated
for comparability purposes.
The Financial Accounting Standards Board (FASB) issued Statement of
Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative
Instruments and Hedging Activities, as amended, which became effective on
January 1, 2001. Under SFAS 133, certain contracts that were not formerly
considered derivatives may now meet the definition of a derivative. PSEG adopted
SFAS 133 effective January 1, 2001. In accordance with SFAS No. 133, all
derivative instruments (including certain derivative instruments embedded in
other contracts) are recognized in the balance sheet at their fair values. The
accounting for changes in the fair value of a derivative depends on the intended
use of the derivative and the resulting designation. For a derivative designated
as a hedge of the exposure to changes in the fair value of a recognized asset or
liability or a firm commitment, the gain or loss is recognized in earnings in
the period of change in tandem with the offsetting loss or gain on the hedged
item attributable to the risk being hedged. For a derivative designated as a
hedge of future cash flows, the effective portion of the derivative's gain or
loss is initially reported as a component of Other Comprehensive Income and
subsequently reclassified into Earnings along with the related effects of the
hedged item. The ineffective portion of the gain or loss is reported in Earnings
immediately. Additionally, contracts that do not in their entirety meet the
definition of a derivative instrument, may contain implicit or explicit terms
that affect some or all of the cash flows or the value of other exchanges
required by the contract in a manner similar to a derivative instrument. These
implicit or explicit terms are considered "embedded derivatives." The effect of
embedding a derivative instrument in another type of contract is that some or
all of the cash flows or other exchanges that otherwise would be required by the
contract, will be modified based on one or more underlying. Embedded derivative
instruments are required to be accounted for as a derivative instrument in
accordance with SFAS 133 if certain criteria are met. PSEG does not have any
fair value hedges, nor does it hold any derivatives that are not designated as
hedges. See Note 9, Adoption of Statement of Financial Accounting Standard No.
133.
The Financial Accounting Standards Board's (FASB) Derivative Implementation
Group (DIG), has issued tentative guidance regarding certain derivative
contracts and eligibility of those contracts for the normal purchases and sales
exceptions. PSEG and its subsidiaries are currently evaluating this tentative
guidance and cannot predict the impact on its financial position or results of
operations, however, such impact could be material.
Note 3. Regulatory Issues
New Jersey Energy Master Plan Proceedings and Related Orders
In August 1999, following the enactment of the New Jersey Electric Discount
and Energy Competition Act, the New Jersey Board of Public Utilities (BPU)
rendered a Final Order relating to PSE&G's rate unbundling, stranded costs and
restructuring proceedings (Final Order) providing, among other things, for the
transfer to an affiliate of all of PSE&G's electric generation facilities, plant
and equipment for $2.443 billion and all other related property, including
materials, supplies and fuel at the net book value thereof, together with
associated rights and liabilities.
Also in the Final Order, the BPU concluded that PSE&G should recover up to
$2.94 billion (net of tax) of its generation-related stranded costs through
securitization of $2.4 billion and an opportunity to recover up to $540 million
(net of tax) of its unsecuritized generation-related stranded costs on a net
present value basis. The $540 million is subject to recovery through a market
transition charge (MTC). Following the issuance of the Final Order, the BPU
issued its order approving PSE&G's petition relating to the proposed
securitization transaction (Finance Order) which authorized, among other things,
the imposition of a non-bypassable transition bond charge (TBC) on PSE&G's
customers; the sale of PSE&G's property right in such charge to a
bankruptcy-remote financing entity; the issuance and sale of $2.525 billion of
transition bonds by such entity as consideration for such property right,
including an estimated $125 million of transaction costs; and the application by
PSE&G of the transition bond proceeds to retire outstanding debt and/or equity.
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PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-Continued
In October and November 1999, appeals were filed challenging the validity
of the Finance Order, as well as the Final Order. In April 2000, the Appellate
Division of the New Jersey Superior Court unanimously rejected the arguments
made by appellants and affirmed the Final Order and Finance Order. In May 2000,
the appellants requested the New Jersey Supreme Court to review certain aspects
of the Appellate Division decision. In July 2000, the New Jersey Supreme Court
granted the requests of the New Jersey Business User's Coalition, the New Jersey
Ratepayer Advocate and Co-Steel Raritan, an individual PSE&G customer. On
December 6, 2000, by a vote of 4 to 1, the New Jersey Supreme Court issued its
order affirming the judgment of the Appellate Division. The 10-day period during
which a party may request reconsideration of this order has expired and thus the
New Jersey Supreme Court decision is final. As with any New Jersey Supreme Court
decision, a party may request the court to enlarge this 10-day period under its
rules. However, Management believes that, in light of the language of the
court's order determining that it is in the public interest to expedite the
disposition of the appeals, this relief would be extraordinary and that
reconsideration would not be granted in any event. Although the opinions of the
New Jersey Supreme Court justices relating to the order have not been issued,
that does not affect the finality of the order.
In August 2000, in compliance with the Final Order, PSE&G transferred its
electric generation business to Power and its subsidiaries in exchange for
Power's promissory note in the amount of $2.786 billion.
On January 31, 2001, $2.525 billion of transition bonds (non-recourse asset
backed securities) were issued by PSE&G Transition Funding LLC, a
bankruptcy-remote, wholly-owned subsidiary of PSE&G, in eight classes with
maturities ranging from 1 year to 15 years. Also on January 31, 2001, PSE&G
received payment from Power on its $2.786 billion promissory note used to
finance the transfer of its generation business. The proceeds from these
transactions were used to pay for certain debt issuance and related costs for
securitization, retire a portion of PSE&G's outstanding short-term debt, reduce
PSE&G common equity, loan funds to PSEG and make various short-term investments.
On March 6, 2001, Co-Steel filed a Petition of Writ of Certiorari
(Petition) with the United States Supreme Court seeking limited review of the
New Jersey Supreme Court decision, the granting of which is entirely
discretionary with the Court. In order to be considered, the Petition must be
made within 90 days of the final state supreme court order and must demonstrate
that an important federal question was decided by the state court. The Clerk of
the United States Supreme Court (Clerk) has directed that briefs in opposition
to the Petition will be due 30 days after the New Jersey written opinions are
received. On March 19, 2001, the RPA filed a letter with the Clerk asking the
Court to confirm that the RPA was not otherwise out of time to file a Petition.
The Clerk indicated in response that the time for requesting certiorari began to
run on December 6, 2000.
Asset Transfer to Power
As noted above, PSE&G transferred its electric generating business and
wholesale power contracts to Power and its subsidiaries in August 2000. The
transfer price, as specified in the BPU order, was $2.443 billion plus $343
million for other generating related assets and liabilities. Because the
transfer was between affiliates, PSE&G and Power recorded the sale at the net
book value of the assets and liabilities rather than the transfer price. The
difference between the total transfer price and the net book value of the
generation-related assets and liabilities was recorded as an equity adjustment
on PSE&G's and Power's respective Consolidated Balance Sheets. These amounts are
eliminated on PSEG's consolidated financial statements. Power settled the
promissory note on January 31, 2001, with funds provided from PSEG in the form
of equity and loans.
Note 4. Regulatory Assets and Liabilities
PSEG deferred the following regulatory assets and liabilities on the
Consolidated Balance Sheets:
March 31, December 31,
2001 2000
--------------- -----------------
(Millions of Dollars)
Regulatory Assets:
Stranded Costs to be Securitized........................... $4,273 $4,093
SFAS 109 Income Taxes...................................... 311 285
OPEB Costs................................................. 227 232
Societal Benefits Charges (SBC)............................ 68 135
Underrecovered Gas Costs................................... 54 --
Environmental Costs........................................ 74 13
Unamortized Loss on Reacquired Debt and Debt Expense....... 101 104
Non-Utility Market Transition Charge....................... 22 7
Other...................................................... 108 126
--------------- -----------------
Total Regulatory Assets................................ $5,238 $4,995
=============== =================
Regulatory Liabilities:
Excess Depreciation Reserve................................ $412 $444
Overrecovered Gas Costs.................................... -- 26
--------------- -----------------
Total Regulatory Liabilities........................... $412 $470
=============== =================
Note 5. Commitments and Contingent Liabilities
Pending Asset Purchases
Delmarva Power and Light Company (DP&L) and Atlantic City Electric Company
(ACE), subsidiaries of Conectiv, are co-owners of the Salem Nuclear Generating
Station (Salem) and the Peach Bottom Atomic Power Station (Peach Bottom) with
Power and Exelon Generation LLC (Exelon). Additionally, Power and ACE are
co-owners of the Hope Creek Generating Station (Hope Creek). In 1999, Power
entered into agreements with Conectiv, DP&L, ACE and Exelon pursuant to which
Power would acquire all of DP&L's and ACE's interests in Salem and Hope Creek
and half of DP&L's and ACE's interest in Peach Bottom (a total of 544 MW) for a
purchase price of $15.4 million plus the net book value of nuclear fuel at the
respective closing dates. In December 2000, the DP&L portion of the transaction
(246 MW) closed. In October 2000, Power entered into a Wholesale Transaction
Confirmation agreement (Agreement) with ACE under which Power obtains 298 MW of
generation capacity and output representing the portion of ACE's interest in
Salem, Hope Creek and Peach Bottom to be acquired. Under this Agreement, Power
receives all revenue and pays all expenses associated with this 298 MW of
generating capacity and output through the date that the purchase transaction
closes. Power has been advised by Conectiv that the Ratepayer Advocate, by
letter to the BPU dated October 26, 2000, has objected to and challenged this
financial transaction.
Hazardous Waste
The New Jersey Department of Environmental Protection (NJDEP) regulations
concerning site investigation and remediation require an ecological evaluation
of potential injuries to natural resources in connection with a remedial
investigation of contaminated sites. The NJDEP is presently working with the
industry to develop procedures for implementing these regulations. These
regulations may substantially increase the costs of environmental investigations
and remediations, where necessary, particularly at sites situated on surface
water bodies. Power and predecessor companies owned and/or operated certain
facilities situated on surface water bodies, certain of which are currently the
subject of remedial activities. The financial impact of these regulations on
these projects is not currently estimable. PSEG does not anticipate that the
compliance with these regulations will have a material adverse effect on its
financial position, results of operations or net cash flows.
Manufactured Gas Plant Remediation Program
PSE&G is currently working with the NJDEP under a program (Remediation
Program) to assess, investigate and, if necessary, remediate environmental
conditions at PSE&G's former manufactured gas plant sites. To date, 38 sites
have been identified. The Remediation Program is periodically reviewed and
revised by PSE&G based on regulatory requirements, experience with the
Remediation Program and available remediation technologies. The long-term costs
of the Remediation Program cannot be reasonably estimated, but experience to
date indicates that approximately $20 million per year could be incurred over a
period of about 30 years and that the overall cost could be material. The costs
for this remediation effort are recovered through the SBC.
Net of recoveries, costs incurred through March 31, 2001 for the
Remediation Program amounted to $129 million. In addition, at March 31, 2001,
PSE&G's estimated liability for remediation costs through 2003 aggregated $74
million. Expenditures beyond 2003 cannot be reasonably estimated.
Passaic River Site
The United States Environmental Protection Agency (EPA) has determined that
a six mile stretch of the Passaic River in Newark, New Jersey is a "facility"
within the meaning of that term under the Federal Comprehensive Environmental
Response, Compensation and Liability Act of 1980 (CERCLA) and that, to date, at
least thirteen corporations, including PSE&G, may be potentially liable for
performing required remedial actions to address potential environmental
pollution at the Passaic River "facility." PSE&G and certain of its predecessors
operated industrial facilities at properties within the Passaic River
"facility," comprised of four former manufactured gas plants (MGP), one
operating electric generating station and one former generating station. Costs
to clean up former MGPs are recoverable from utility customers under the SBC.
The operating electric generating station has been transferred to Power, which
is responsible for its remediation. PSEG cannot predict what action, if any, the
EPA or any third party may take against PSE&G and/or Power with respect to these
matters, or in such event, what costs PSE&G and/or Power may incur to address
any such claims. However, such costs may be material.
New Source Review
The EPA and NJDEP issued a demand to PSE&G in March 2000 under section 114
of the Federal Clean Air Act (CAA) requiring information to assess whether
projects completed since 1978 at the Hudson and Mercer coal burning units were
implemented in accordance with applicable New Source Review regulations. As a
result of the transfer of the generating business by PSE&G to Power, the
responsibility for these environmental requirements now rests with Power. Power
completed its response to the section 114 information request in November 2000.
Based upon the information provided to the EPA it is likely that the EPA will
seek to enforce the requirements of the New Source Review program at Hudson 2
and Mercer 1 and 2. Power is currently in discussions with the EPA and NJDEP to
resolve the matter. However, it is uncertain whether these discussions will be
successful and capital costs of compliance could approximate $300 million. These
costs are not currently included in Power's business plans.
The EPA indicated that it is considering enforcement action against Power
under its PSD rules relating to the construction that is currently in progress
for Bergen 2, scheduled for operations in 2002. The EPA maintains that
Prevention of Significant Deterioration (PSD) requirements are applicable to
Bergen 2, thereby requiring Power to obtain a permit prior to the commencement
of construction. To obtain such a permit, an applicant must demonstrate that the
additional emission source will not cause significant deterioration of the air
shed in the vicinity of the plant. The time required to obtain such a permit is
estimated at 12-18 months. Power vigorously disputes that PSD requirements are
applicable to Bergen 2 and is continuing construction. The NJDEP has informally
indicated it agrees with Power's position. Settlement discussions are underway
with the EPA.
Note 6. Financial Instruments and Risk Management
PSEG's operations give rise to exposure to market risks from changes in
commodity prices, interest rates, foreign currency exchange rates and securities
prices. PSEG's policy is to use derivative financial instruments for the purpose
of managing market risk consistent with its business plans and prudent business
practices.
Commodity-Related Instruments
Power
At March 31, 2001 and December 31, 2000, Power held or issued commodity and
financial instruments that reduce exposure to price fluctuations from factors
such as weather, environmental policies, changes in demand, changes in supply,
state and Federal regulatory policies and other events. These instruments, in
conjunction with owned electric generating capacity and physical gas supply
contracts, are designed to cover estimated electric and gas customer
commitments. Power use futures, forwards, swaps and options to manage and hedge
price risk related to these market exposures.
At March 31, 2001, Power had outstanding commodity financial instruments
with a notional contract quantity of 53.4 million megawatt-hours (mWh) of
electricity and 14.4 million MMBTU (million British thermal units) of natural
gas. At December 31, 2000, Power had outstanding commodity financial instruments
with a notional contract quantity of 54.0 million mWh of electricity and 67.2
million MMBTU of natural gas. Notional amounts are indicative only of the volume
of activity and are not a measure of market risk.
PSE&G's and Power's energy trading and related contracts have been marked
to market and gains and losses from such contracts were included in earnings.
Power recorded $(10.7)million of unrealized losses in the quarter ended March
31, 2001 and PSE&G recorded $1.6 million of unrealized gains in the quarter
ended March 31, 2000.
The fair value of the financial instruments that are marked-to-market are
based on management's best estimates using over-the counter quotations, exchange
prices, volatility factors and valuation methodology. The estimates presented
herein are not necessarily indicative of the amounts that Power could realize in
a current market exchange. The fair values as of March 31, 2001 and December 31,
2000 and the average fair values for the periods then ended of PSE&G's and
Power's significant financial instruments related to energy commodities are
summarized in the following table:
March 31, 2001 December 31, 2000
--------------------------- ---------------------------
Fair Average Fair Average
Value Fair Value Value Fair Value
--------- ------------ --------- -------------
(Millions of Dollars) (Millions of Dollars)
Futures and Options NYMEX............. $1 $1 $6 $(1)
Physical forwards..................... 25 25 19 23
Options-- OTC......................... 76 110 184 68
Swaps................................. (57) (73) (138) (43)
PSE&G and Power routinely enter into exchange traded futures and options
transactions for electricity and natural gas as part of its wholesale trading
operations. Generally, exchange-traded futures contracts require deposit of
margin cash, the amount of which is subject to change based on market movement
and in accordance with exchange rules. The amount of the margin deposits at
March 31, 2001 and December 31, 2000 was approximately $1 million.
Equity Securities -- Energy Holdings
PSEG Resources Inc. (Resources), a wholly-owned subsidiary of Energy
Holdings, has investments in equity securities and limited partnerships.
Resources carries its investments in equity securities at their approximate fair
value as of the reporting date. Consequently, the carrying value of these
investments is affected by changes in the fair value of the underlying
securities. Fair value is determined by adjusting the market value of the
securities for liquidity and market volatility factors, where appropriate. The
aggregate fair values of such investments which had available market prices at
March 31, 2001 and December 31, 2000 were $65 million and $115 million,
respectively. The decrease in fair value was primarily due to the sale of its
interest in FleetBoston Financial Corporation which had a book value of $30
million on December 31, 2000 and lower valuation of publicly traded equity
securities within Resources' portfolio. The potential change in fair value
resulting from a hypothetical 10% change in quoted market prices of these
investments amounted to $5 million and $9 million at March 31, 2001 and December
31, 2000, respectively.
Foreign Currencies -- Energy Holdings
As of March 31, 2001, Global and Resources had international assets of
approximately $2.023 billion and $1.210 billion, respectively.
Resources' international investments are primarily leveraged leases of
assets located in the Netherlands, Australia, the United Kingdom, Germany, China
and New Zealand with associated revenues denominated in U.S. dollars, and
therefore, not subject to foreign currency risk.
Global's international investments are primarily in projects that generate
or distribute electricity in Argentina, Brazil, Chile, China, India, Italy,
Peru, Poland, Tunisia and Venezuela. Investing in foreign countries involves
certain additional risks. Economic conditions that result in higher comparative
rates of inflation in foreign countries are likely to result in declining values
in such countries' currencies. As currencies fluctuate against the $US, there is
a corresponding change in Global's investment value in terms of the $US. Such
change is reflected as an increase or decrease in the investment value and other
comprehensive income, a separate component of stockholder's equity. As of March
31, 2001, net foreign currency devaluations have reduced the reported amount of
Energy Holdings' total stockholder's equity by $205 million, $154 million of
which was caused by the devaluation of the Brazilian Real.
Credit Risk
Credit risk relates to the risk of loss that PSEG and its subsidiaries
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 its exposure to 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 may allow for the netting of
positive and negative exposures associated with a single counterparty.
The deregulation of the California power market has produced significant
unanticipated results in the past year. The California Public Utility
Commission, (CPUC) as part of deregulation, froze the rates that utilities can
charge their retail and business customers in California and prohibited the
utilities from buying power on a forward basis, while wholesale power prices
were not subjected to limits. In the past year, an increase in demand coupled
with a reduced supply of power has caused a severe imbalance in the market. Such
imbalance has led to unprecedented wholesale prices.
As a result of this situation, two major California utilities that are
subject to the retail price cap, including Pacific Gas & Electric Company
(PG&E), have significantly underrecovered from customers costs paid for power.
As a consequence, these utilities have defaulted under a variety of contractual
obligations. On April 6, 2001, PG&E filed for reorganization under Chapter 11 of
the U.S. Bankruptcy Code.
GWF, Hanford and Tracy Qualifying Facilities (QF) have continued to honor
their contractual obligations to PG&E under existing QF contracts. To date they
have refrained from pursuing collection remedies with respect to PG&E's default,
and have been actively involved in being part of the solution to stabilize
energy prices through the application of a long-term energy pricing methodology
(for a five-year period). On March 27, 2001, the CPUC approved a plan to assure
the state's QFs are paid for future deliveries of energy within 15 days of the
receipt of an invoice. The CPUC's plan, while immediately effective, did not
address amounts due such facilities for past due receivables related to energy
delivered since December 2000. In addition to the payment issue, the CPUC also
approved a 40% increase in electric retail rates to help the state's utilities
recover significantly higher wholesale energy costs. It is expected further that
legislation will be developed to enable the California utilities to finance,
over a longer term, the difference between the wholesale prices that have been
paid and the retail prices received during the latter half of 2000. On April 11,
2001, management at Global's project affiliates received a letter from PG&E
addressed to QF owners stating that they intended to pay the QFs for power
delivered commencing April 6, 2001 at 9:00 A.M. (the date and time of their
bankruptcy petition). On April 17, 2001 and May 2, 2001, the project affiliates
received $3 million and $5 million respectively, from PG&E representing payments
for all energy delivered for the period from the time of the bankruptcy petition
through April 30, 2001. Global cannot predict the timing or ultimate outcome of
the legislative process, or the payment of future amounts by PG&E.
As of December 31, 2000, GWF, Hanford and Tracy had combined receivables
due from PG&E, for all plants amounting to $40 million. Of this amount, $8
million had been reserved as an allowance for doubtful accounts resulting in a
net receivable balance of $32 million. Global's pro-rata share of this net
receivable was $15 million.
As of April 6, 2001, GWF, Hanford and Tracy had combined receivables due
from PG&E, for all plants amounting to $62 million. Of this amount,
approximately $20 million had been reserved as an allowance for doubtful
accounts resulting in a net receivable balance of approximately $42 million.
Global's pro-rata share of this net receivable was approximately $20 million.
Interest Rates
PSEG is subject to the risk of fluctuating interest rates in the normal
course of business. PSEG's policy is to manage interest rate risk through the
use of fixed rate debt, floating rate debt and interest rate swaps. As of March
31, 2001, a hypothetical 10% change in market interest rates would result in a
$11 million change in annual interest costs related to short-term and floating
rate debt at PSEG.
Note7. Income Taxes
PSEG's effective income tax rate is as follows:
Quarter Ended
March 31,
-----------------------------
2001 2000
----------- ------------
Federal tax provision at statutory rate............................. 35.0% 35.0%
New Jersey Corporate Business Tax, net of Federal benefit........... 5.9% 5.9%
Other-- net......................................................... (3.3)%
(0.5)%
----------- ------------
Effective Income Tax Rate...................................... 37.6% 40.4%
=========== ============
PSEG's effective tax rate differs from the statutory income tax rate
primarily due to the accruals at the rate of 10% of Global's foreign income due
to the incremental cost associated with the repatriation of foreign earnings.
Note 8. Financial Information by Business Segments
Information related to the segments of PSEG's business is detailed below:
- - ----------------------------------------------------------------------------------------------------------------------------
Energy Consolidated
Generation Trading T & D Resources Global Technologies Other (A) Total
----------- -------- -------- ---------- ------- ------------ ---------- -------------
(Millions of Dollars)
For the Quarter Ended
March 31, 2001:
Total Operating Revenues... $561 $587 $1,952 $33 $84 $102 $(505) $2,814
Income Before $72 $30 $109 $3 $48 $ (3) $ (5) $254
Extraordinary Item and
Cumulative Effect of a
Change in Accounting
Principle..................
Extraordinary Loss on Early
Retirement of Debt........... -- -- -- -- (2) -- -- (2)
Cumulative Effect of a Change in
Accounting Principle......... -- -- -- -- 9 -- -- 9
Segment Net Income (Loss).. $72 $30 $109 $3 $55 $(3) $(5) $261
=========== ======== ======== ========== ======= ============ ========== =============
- - ----------------------------------------------------------------------------------------------------------------------------
For the Quarter Ended
March 31, 2000:
Total Operating Revenues... $530 $614 $1,121 $66 $38 $113 $ 1 $2,483
Segment Net Income (Loss).. $109 $17 $122 $27 $4 $ (6) $(3) $270
=========== ======== ======== ========== ======= ============ ========== =============
- - ----------------------------------------------------------------------------------------------------------------------------
As of March 31, 2001:
Total Assets............... $3,665 $522 $13,767 $2,547 $2,542 $330 $(1,679) $21,694
=========== ======== ======== ========== ======= ============ ========== =============
- - ----------------------------------------------------------------------------------------------------------------------------
As of December 31, 2000:
Total Assets............... $3,439 $1,091 $15,267 $2,564 $2,271 $312 $(3,418) $21,526
=========== ======== ======== ========== ======= ============ ========== =============
- - --------------------------------------------------------------------------------------------------------------------------
(A) PSEG's other activities include amounts applicable to PSEG (parent
corporation), Energy Holdings (parent corporation), Enterprise Group
Development Corporation and intercompany eliminations, primarily relating
to intercompany transactions between Power and PSE&G. The net losses
primarily relate to financing and certain administrative and general costs
at the parent corporations.
Geographic information for PSEG is disclosed below. The foreign investments
and operations noted below were made through Energy Holdings.
Revenues (1) Identifiable Assets
-------------------------- -------------------------------------
Quarter Ended
March 31, March 31, December 31,
-------------------------- -------------- -----------------
2001 2000 2001 2000
---------- ---------- -------------- -----------------
(Millions of Dollars) (Millions of Dollars)
United States......................... $2,763 $2,435 $18,255 $17,806
Foreign Countries (2)................. 51 48 3,233 2,990
---------- ---------- -------------- -----------------
Total............................ $2,814 $2,483 $21,488 $20,796
========== ========== ============== =================
Identifiable investments in foreign countries include:
Netherlands $825 $815
Chile and Peru (3) 550 520
Argentina 485 470
Brazil (4) 293 295
Other 1,080 890
--------------- -----------------
Total $3,233 $2,990
=============== =================
<FN>
(1) Revenues are attributed to countries based on the locations of the
investments. Certain of Global's revenue includes its share of the net
income from joint ventures recorded under the equity method of accounting.
(2) Total assets are net of foreign currency translation adjustment of $(229)
million (pre-tax) as of March 31, 2001 and $(225) million (pretax) as of
December 31, 2000.
(3) Amount is net of foreign currency translation adjustment of $(43) million
(pre-tax) as of March 31, 2001 and $(44) million (pre-tax) as of December
31, 2000.
(4) Amount is net of foreign currency translation adjustment of $(171) million
(pre-tax) as of March 31, 2001 and $(167) million (pre-tax) as of December
31, 2000.
</FN>
Note 9. Adoption of Statement of Financial Accounting Standards No. 133
The nature of PSEG's bbusiness activities involves the management of
various financial and market risks, including those related to changes in
interest rates, equity prices, currency exchange rates, and commodity prices.
PSEG's policy is to use derivative financial instruments to manage certain of
those risks, consistent with its business plans and prudent practices. PSEG has
a Risk Management Committee comprised of executive officers, which utilizes an
independent risk oversight function to ensure compliance with corporate policies
and prudent risk management practices for all of its subsidiaries. The January
1, 2001 accounting change described above affected only the pattern and timing
of non-cash accounting recognition.
At January 1, 2001, PSEG's recorded a cumulative effect from adopting this
accounting change, as follows:
Other
Comprehensive
Earnings Income
-------------- ----------------
(Millions of Dollars)
Fair value of derivative assets............. $22.7 $ 0.4
Fair value of derivative liabilities........ -- (41.0)
Income tax effects.......................... (7.9) 14.2
Minority interests effects.................. (6.0) 12.0
----------- ----------------
Total cumulative effect of a change in
accounting principle...................... $ 8.8 $(14.8)
----------- ----------------
The cumulative effect on earnings included one significant element
associated with a Power Purchase Agreement (PPA). An Energy Holdings' affiliate
entered into a PPA that provides for indexation of foreign currencies to the $US
over the tariff collection period. The indexation provides for an increased
amount of foreign currency to be provided to the affiliated entity in the event
of currency devaluation.
The indexation portion of the PPA is considered an embedded derivative and
has been recognized and valued separately as a derivative instrument. As
currencies devalue/revalue in relation to the $US, the derivative
increases/decreases in value equal to the discounted present value of additional
units of foreign currency (measured in $US) over the life of the PPA. This
increased/decreased value is reported on the balance sheet as an
asset/liability. To the extent that such indexation is provided to hedge foreign
currency debt exposure, the offsetting amount is recorded in Other Comprehensive
Income. Amounts will be amortized from Other Comprehensive Income to Earnings
over the life of the debt upon commercial operation of the project, expected to
occur in the third quarter of 2001. To the extent such indexation is provided to
hedge an equity return in $US, the offsetting amount is recorded in Earnings.
The total value of this embedded derivative was recorded on January 1, 2001 as a
transition adjustment to Earnings as required by SFAS 133. All changes in fair
value of this embedded derivative recorded subsequent to January 1, 2001 impact
both Other Comprehensive Income and Earnings, as described above.
The cumulative effect on Other Comprehensive Income was attributable to
marking to market interest rate swaps used to hedge variable-rate borrowings.
Decreases in the fair values of these instruments subsequent to January 1, 2001,
were attributable to declines in interest rates since inception of the hedging
arrangements and will be recognized contemporaneously in earnings in future
periods by offsetting lower interest expense associated with the hedged items.
A reconciliation of current period changes, net of applicable income taxes,
in the separate component of Other Comprehensive Income follows.
(Millions of Dollars)
Transition adjustment as of January 1, 2001....... $(14.8)
Current period declines in fair value - net....... (0.6)
Reclassification to earnings - net................ 0.2
--------------
Balance at March 31, 2001......................... $(15.5)
--------------
As of March 31, 2001 the fair values of PSEG's derivative assets and
liabilities were $31 million and $46 million, respectively. The fair values of
such derivative assets and liabilities were recorded on the consolidated balance
sheet in Other Assets and Other Noncurrent Liabilities, respectively.
Additional disclosures required by SFAS No. 133 are provided in the
following paragraphs.
Hedges of Future Cash Flows
The ineffective portion of changes in fair values of interest rate swaps,
reported in first quarter earnings, amounted to $0.6 million, net of income
taxes and minority interest. This amount was recorded in Other Income.
At March 31, 2001, the maximum term of derivative instruments that hedge
forecasted transactions, except those related to payment of variable interest on
existing financial instruments, was twenty years subsequent to the commencement
of commercial operation of an electric generation facility of an Energy
Holdings' affiliate in Rades, Tunisia, expected to occur in the third quarter of
2001.
Hedges of Recognized Assets, Liabilities and Firm Commitments - Embedded
Derivative
The indexation portion of the PPA that hedged foreign currency equity
exposure reported in first quarter earnings, amounted to $1 million, net of
income taxes and minority interest.
The FASB's Derivative Implementation Group has issued tentative guidance
regarding certain derivative contracts and eligibility of those contracts for
the normal purchases and sales exceptions. Energy Holdings and its subsidiaries
are currently evaluating this tentative guidance in light of its potential
impacts on the implementation of SFAS 133 and cannot predict the impact on its
financial position or results of operations, however, such impact could be
material.
- - --------------------------------------------------------------------------------
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
- - --------------------------------------------------------------------------------
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS-Concluded
Note 10. Comprehensive Income
Comprehensive Income, Net of Tax:
Quarters Ended
March 31,
-----------------------------
2001 2000
------------ ------------
(Millions of Dollars)
Net income.......................................................... $261 $270
Foreign currency translation, (net of tax of $0.2 and
$(3.1) for 2001 and 2000, respectively)........................ (2) 28
Cumulative effect of a change in accounting principle
(net of tax of $8 and net of $3 and minority interest of $12). (15) --
Derivatives qualifying as hedges.................................... (5 --
------------ ------------
Comprehensive income........................................... $239 $298
============ ============
Note. 11 Subsequent Events
On April 9 2001, Power, in a private placement, issued $500 million of
6.875% Senior Notes due 2006, $800 million of 7.75% Senior Notes due 2011 and
$500 million 8.625% Senior Notes due 2031. The net proceeds from the sale of the
Senior Notes were used primarily for the repayment of loans from PSEG. Power
plans to file a registration statement with the SEC relating to an exchange
offer for, or the resale of, these Senior Notes later in 2001. Each series of
Senior Notes received investment grade ratings from Moody's Investors Service,
Fitch, Inc. and Standard & Poor's Rating Services. In connection with the
issuance of the Senior Notes, the forward starting interest rate swaps were
terminated for $5.3 million .
- - --------------------------------------------------------------------------------
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
- - --------------------------------------------------------------------------------
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Following are the significant changes in or additions to information
reported in the Public Service Enterprise Group Incorporated (PSEG) 2000 Annual
Report on Form 10-K affecting the consolidated financial condition and the
results of operations of PSEG and its subsidiaries. This discussion refers to
the Consolidated Financial Statements (Statements) and related Notes to
Consolidated Financial Statements (Notes) of PSEG and should be read in
conjunction with such Statements and Notes.
Results of Operations
Earnings (Losses)
-------------------------------
Quarter Ended
March 31,
-------------------------------
2001 2000
------------ ------------
(Millions of Dollars)
PSE&G......................... $109 $248
Energy Holdings............... 54 25
Power......................... 102 --
PSEG*......................... (4) (3)
------------ ------------
Total PSEG.............. $261 $270
============ ============
Contribution to Earnings
Per Share
(Basic and Diluted)
-------------------------------
Quarter Ended
March 31,
-------------------------------
2001 2000
-------------- ------------
PSE&G.......................... $0.52 $1.15
Energy Holdings................ 0.26 0.11
Power.......................... 0.49 --
PSEG*.......................... (0.02) (0.01)
-------------- ------------
Total PSEG............... $1.25 $1.25
============== ============
* Includes after tax effect of interest on certain financing transactions and
certain general and administrative costs.
Basic and diluted earnings per share of PSEG common stock (Common Stock)
were $1.25 for the quarter ended March 31, 2001, representing no change from the
comparable 2000 period.
PSE&G's and Power's contribution to earnings per share of Common Stock for
the quarter ended March 31, 2001 decreased $0.14 or 12% from the comparable 2000
period. The decrease for the quarter ended March 31, 2001 was primarily due to
an additional 2% electric rate reduction combined with the amortization of the
stranded cost regulatory asset beginning in February 2001. These decreases were
partially offset by higher profits from trading activities and increased sales
due to colder weather.
Energy Holdings contribution to earnings per share of Common Stock for the
quarter ended March 31, 2001 increased $0.15 from the comparable 2000 period,
primarily due to payments received relating to Global's withdrawal from its
interest in the Eagle Point Cogeneration Partnership which are expected to total
up to $290 million over the next five years, subject to certain contingencies.
As a result of PSEG's stock repurchase program which began in September
1998, earnings per share of Common Stock for the quarter ended March 31, 2001
increased $0.04 from the comparable 2000 period. A total of 24.2 million shares
were repurchased at a cost of approximately $905 million under this program as
of March 31, 2001.
Revenues
Generation
Generation revenues increased $31 million or 6% for the quarter ended March
31, 2001 from the comparable period in 2000 primarily due to an
increase associated with increased load served under the BGS contract with
PSE&G. This increased load is due to customers returning to PSE&G from third
party suppliers (TPS) as wholesale market prices have typically exceeded fixed
BGS rates. As of March 31, 2001 TPS were serving approximately 6% of the
customer load traditionally served by PSE&G as compared to the March 31, 2000
level of 11%. Also contributing to the increase were $9 million in higher
ancillary services revenues and approximately $9 million in revenues from new
developments subsequent to the first quarter of 2000. The increases was
partially offset by the additional 2% rate reduction, which was effective as of
February 7, 2001, which reduced revenues by approximately $12 million.
Transmission and Distribution
Transmission and Distribution revenues increased $325 million or 29% for
the quarter ended March 31, 2001 from the comparable period in 2000 primarily
due to increases in natural gas prices being passed along to gas customers under
certain transportation only contracts. Under these contracts, PSE&G is
responsible only for delivery of gas to its customers. Such customers are
responsible for payment to PSE&G for the cost of the commodity and as PSE&G's
costs on behalf of these customers increase, the customer's rates to cover the
costs of gas will increase. Also contributing to this increase were higher sales
resulting from colder weather in the first quarter of 2001 as compared to the
same period in 2000 and higher rates approved by the BPU to allow PSE&G to
recover for increasing natural gas costs.
Trading
Trading revenues decreased $27 million or 4% for the quarter ended March
31, 2001 from the comparable period in 2000 due to lower trading volumes
resulting from increased market volatility. These decreased revenues were more
than offset by decreased trading costs as discussed below in Energy Costs.
Other
Other revenues increased $2 million or 2% for the quarter ended March 31,
2001 as compared to the same period in 2000. Revenues in 2001 were favorably
impacted by Global's withdrawal from its interest in the Eagle Point
Cogeneration Partnership in exchange for a series of payments through 2005,
expected to total up to $290 million. Global realized an increase in revenues of
$46 million for the quarter ended March 31, 2001, as compared to the same period
in 2000 primarily related to the withdrawal from the Eagle Point Cogeneration
Partnership. In addition, revenues were further enhanced by an increase of $9
million due to higher leveraged lease income from continued investment by
Resources in such financing transactions. These increases were partially offset
by lower Net Investments Gains (Losses) of $46 million primarily due to a net
decrease in the carrying value of publicly traded equity securities in
Resources' leveraged buyout funds.
Energy Costs
Energy Costs decreased $26 million or 3% for the quarter ended March 31,
2001 from the comparable 2000 period primarily due to $49 million in lower costs
related to trading activities, resulting from lower trading volumes. Also
contributing to the decreased Energy Costs were lower costs for nuclear
generation. The decreases were partially offset by higher fuel costs for
generation, including $31 million resulting from higher natural gas prices.
Gas Costs
Gas Costs increased $307 million or 64% for the quarter ended March 31,
2001 from the comparable 2000 period primarily due to the higher prices for
natural gas. Also contributing to the increase was higher demand for natural gas
due to colder weather in the first quarter of 2001 as compared to the same
period in 2000.
Operations and Maintenance
Operations and Maintenance expense increased $60 million or 13% primarily
due to planned outage work in the first quarter of 2001, lower capital project
work for the quarter ended March 31, 2001 as compared to the same period in
2000, higher expenses relating to projects going into operation subsequent to
the first quarter of 2000 and a change in the accrual for the anticipated cost
of removal for generating stations.
Depreciation and Amortization
Depreciation and Amortization expense increased $18 million or 20% for the
quarter ended March 31, 2001 from the comparable 2000 period. The increase was
primarily due the amortization of the regulatory asset recorded for PSE&G's
stranded costs beginning in February 2001.
Interest Expenses
Interest Expense increased $22 million or 16% for the quarter ended March
31, 2001 from the comparable 2000 period primarily due to increased long-term
debt.
Liquidity and Capital Resources
PSEG
PSEG is a holding company and, as such, has no operations of its own. The
following discussion of PSEG's liquidity and capital resources is on a
consolidated basis, noting the uses and contributions of PSEG's three direct
operating subsidiaries, PSE&G, Power and Energy Holdings.
Dividend payments on Common Stock were $0.54 per share and totaled
approximately $112 million and $117 million for the quarters ended March 31,
2001 and 2000, respectively. Future dividends declared will be dependent upon
PSEG's future earnings, cash flows, financial requirements, alternate investment
opportunities and other factors.
PSE&G
On January 31, 2001, $2.525 billion of transition bonds (non-recourse asset
backed securities) were issued by PSE&G Transition Funding LLC, a
bankruptcy-remote, wholly-owned subsidiary of PSE&G. PSE&G also received payment
from Power on its $2.786 billion Promissory Note used to finance the transfer of
PSE&G's generation assets to Power. The proceeds from these transactions were
used to pay for certain debt issuance and related costs for securitization,
redeem a portion of PSE&G's outstanding short-term debt, reduce PSE&G common
equity by $2.265 billion, loan funds to PSEG of $1.084 billion and make various
short-term investments. These funds are expected to be used for further debt
and/or equity reductions in 2001 including payment of maturing and certain
redeemable securities. Any inability to obtain required additional external
capital or to extend or replace maturing debt and/or existing agreements at
current levels and reasonable interest rates may affect PSE&G's financial
condition, results of operations and net cash flows.
Cash generated from PSE&G's transmission and distribution business is
expected to provide the majority of the funds for PSE&G's business needs. Since
1986, PSE&G has made regular cash payments to PSEG in the form of dividends on
outstanding shares of PSE&G's common stock. PSE&G paid common stock dividends of
$112 million and $117 million to PSEG for the quarters ended March 31, 2001 and
2000, respectively. These amounts were used to fund PSEG's Common Stock
dividends.
In March 2001, PSE&G redeemed all of its $150 million of 9.375% Series A
cumulative income preferred securities, all of its $75 million of 5.97%
preferred stock, $15 million of its 6.75% preferred stock and $52 million of its
floating rate notes due December 7, 2002.
Power
In 2000, Power financed the transfer of the generation assets from PSE&G
through the issuance of a $2.786 billion promissory note. On January 31, 2001,
through $1.2 billion of equity infusions and $1.62 billion of loans from PSEG,
Power repaid this note to PSE&G. On April 9, 2001, Power issued $1.8 billion of
its Senior Notes, the proceeds of which were used primarily to replace its
interim financing from PSEG. It is expected that Power's future capital needs
will be funded with cash generated from operations and may be supplemented with
external financings, equity infusions from PSEG and other project financing
alternatives as dictated by Power's growth strategy. Any inability to obtain
required additional external capital at reasonable interest rates may affect
Power's financial condition, results of operations and net cash flows.
Energy Holdings
It is intended that Global and Resources will continue to provide the
earnings and cash flow for Energy Holdings' long-term growth. Resources'
investments are designed to produce immediate cash flow and earnings that enable
Global and Energy Technologies to focus on longer investment horizons. During
the next five years, Energy Holdings will need material capital to fund its
planned growth. In addition to cash generated from operations, Energy Holdings'
growth will be funded through external financings and equity infusions from
PSEG.
Over the next several years, Energy Holdings, certain of its project
affiliates and PSEG Capital will be required to refinance maturing debt, incur
additional debt and provide equity to fund investment activity. Any inability to
obtain required additional external capital or to extend or replace maturing
debt and/or existing agreements at current levels and reasonable interest rates
may affect Energy Holdings' financial condition, results of operations and net
cash flows.
Regulatory Restrictions
As a result of a 1992 BPU proceeding concerning the impact of PSEG's
non-utility investments (Focused Audit) on PSE&G, the BPU approved a plan which,
among other things, provided that: (1) PSEG would not permit PSEG's non-utility
assets to exceed 20% of PSEG's consolidated assets without prior notice to the
BPU (as of December 31, 2000, these assets were in excess of the 20% limit and
the required notice had been given); (2) the PSE&G Board of Directors would
provide an annual certification that the business and financing plans of Energy
Holdings will not adversely affect PSE&G; (3) PSEG would (a) limit debt
supported by the minimum net worth maintenance agreement between PSEG and PSEG
Capital to $650 million and (b) make a good-faith effort to eliminate such
support by May 2003; and (4) Energy Holdings would pay PSE&G an affiliation fee
of up to $2 million a year to be applied by PSE&G to reduce utility rates.
The Final Order addressed the Focused Audit, noting that PSEG's
non-regulated assets would likely exceed 20% and that, due to significant
changes in the industry and, in particular, PSEG's corporate structure as a
result of the Final Order, modifications to or relief from the Focused Audit
might be warranted. In March 2000, PSE&G submitted a letter to the BPU notifying
the BPU of its intention to make a filing to modify the terms of the Focused
Audit within 120 days after the Final Order becomes final and non-appealable. In
December 2000, the New Jersey Supreme Court affirmed the appellate decision
upholding the Final Order (see Note 2. Regulatory Issues). Also, Energy Holdings
believes that, if still required, it is capable of eliminating PSEG support of
PSEG Capital debt within the time period set forth in the Focused Audit.
Regulatory oversight by the BPU to ensure that there is no harm to utility
customers from PSEG's non-utility investments is expected to continue. PSEG and
PSE&G believe that these issues will be satisfactorily resolved, although no
assurances can be given. In addition, if PSEG were no longer exempt under the
Public Utility Holding Company Act (PUHCA), PSEG and its subsidiaries would be
subject to additional regulation by the SEC with respect to financing and
investing activities, including the amount and type of non-utility investments.
PSEG believes, however, that this would not have a material adverse impact on
its financial condition, results of operations and net cash flows.
Capital Requirements
PSE&G
PSE&G has substantial commitments as part of its ongoing construction
programs. These programs are continuously reviewed and periodically revised as a
result of changes in economic conditions, revised load forecasts, business
strategies, site changes, cost escalations under construction contracts,
requirements of regulatory authorities and laws, the timing of and amount of
electric and gas transmission and/or distribution rate changes and the ability
of PSE&G to raise necessary capital.
Construction expenditures are related to improvements in PSE&G's
transmission and distribution system, gas system and common facilities. For the
quarter ended March 31, 2001 PSE&G had net plant additions of $63 million,
excluding Allowance for Funds Used During Construction (AFDC).
Power
Construction expenditures were related to acquisitions by Power and
improvements in Power's existing power plants. Power had net plant additions for
the quarter ended March 31, 2001 of $282 million, excluding capitalized
interest. Power's growth strategy is designed to increase its operating
generating portfolio to 20,000 MW by 2005. Changes in environmental regulations
and unexpected impacts of existing regulations could impact both Power's
construction and growth strategy as well as the capital expenditure amounts. For
further information, including New Source Review requirements under the Federal
Clean Air Act (CAA), see Note. 4. Commitments and Contingent Liabilities.
Energy Holdings
Energy Holdings plans to continue the growth of Global and Resources.
Energy Holdings will assess the growth prospects and opportunities for Energy
Technologies' business before committing substantial amounts of additional
capital. For the quarter ended March 31, 2001, Energy Holdings' subsidiaries
made net investments totaling approximately $124 million. These investments
included $59 million by Global, primarily related to incremental investments in
certain existing generation and distribution projects including those in
operation and currently under construction. In addition, Global loaned $60
million to TIE. Factors affecting actual expenditures and investments include
availability of capital and suitable investment opportunities, market volatility
and local economic trends.
In March 2001, Global reached agreement to purchase a 94% equity stake in
Sociedad Austral de Electricidad S.A. (SAESA) and all of its subsidiaries from
Compania de Petroleos de Chile S.A. (COPEC). Additionally, Global reached
agreement to purchase from COPEC approximately 14% of Empresa Electrica de la
Frontera S.A. (Frontel) not owned by SAESA. The SAESA group of companies
consists of four distribution companies and one transmission company that
provide service in the southern part of Chile. Additionally, SAESA owns a 50%
interest in the Argentine distribution company Empresa Electrica del Rio Negro
S.A. Collectively, the companies serve more than 615,000 customers. The purchase
price to be paid by Global will total approximately $460 million.
In May 2001, Resources closed its investment of $140 million in a leveraged
lease financing of two electric power stations to Dynegy Power Corp, an
affiliate of Dynegy Inc. The generating stations leased include Roseton, a 1,200
MW gas/oil-fired plant and Danskammer, a 370 MW coal-fired plant, located in
Newburgh, New York.
External Financings
PSEG
At March 31, 2001, PSEG had a committed $150 million revolving credit
facility which will expire in December 2002. At March 31, 2001, there were no
borrowings under this revolving credit facility. In 1999, PSEG entered into an
uncommitted line of credit with a bank with no stated limit. At March 31, 2000,
PSEG had $93 million outstanding under this line of credit.
PSEG has an $850 million commercial paper program to provide funds for
general corporate purposes. On March 31, 2001, PSEG had commercial paper of $206
million outstanding under this program.
To provide liquidity for its commercial paper program, PSEG has a $570
million revolving credit facility expiring in March 2002 and a $280 million
revolving credit facility expiring in March 2005. These agreements are with
groups of banks and provide for borrowings with maturities of up to one year. As
of March 31, 2001 there were no borrowings outstanding under these facilities.
PSE&G
Under its Mortgage, PSE&G may issue new First and Refunding Mortgage Bonds
against previous additions and improvements and/or retired Mortgage Bonds
provided that its ratio of earnings to fixed charges calculated in accordance
with its Mortgage is at least 2:1. At March 31, 2001, PSE&G's Mortgage coverage
ratio was XX:1. As of March 31, 2001, the Mortgage would permit up to $1 billion
aggregate principal amount of new Mortgage Bonds to be issued against previous
additions and improvements. In addition to the refinancing of existing long-term
debt authorized by the BPU in the Final Order, PSE&G will need to obtain BPU
authorization to issue any incremental debt financing necessary for its capital
program. The BPU has authorized PSE&G to issue up to $1 billion of long-term
debt on the basis of previously matured, redeemed or purchased debt through
December 31, 2001, of which $590 million has been issued.
As discussed previously, on January 31, 2001, transition bonds
(non-recourse asset backed securities) in the amount of $2.525 billion were
issued by PSE&G Transition Funding LLC, a bankruptcy-remote, wholly-owned
subsidiary of PSE&G, in eight classes with maturities ranging from 1 year to 15
years.
In March 2001, PSE&G reduced the maximum size of its commercial paper
program from $1.5 billion to $900 million. To provide liquidity for this
program, PSE&G maintains a $450 million revolving credit facility that expires
in June 2001 and a $450 million credit facility that expires in June 2002. As of
March 31, 2001, there were no borrowings outstanding under these facilities.
PSE&G has several uncommitted lines of credit with banks. On March 31,
2001, PSE&G had $155 million of short-term debt outstanding, borrowed against
its uncommitted bank lines of credit.
Power
On April 9, 2001, Power, in a private placement, issued $500 million of
6.875% Senior Notes due 2006, $800 million of 7.75% Senior Notes due 2011 and
$500 million 8.625% Senior Notes due 2031. The net proceeds from the sale of the
Senior Notes were used primarily for the repayment of loans from PSEG. Power
plans to file a registration statement with the SEC relating to an exchange
offer for, or the resale of, these Senior Notes later in 2001. Each series of
Senior Notes received investment grade ratings from Moody's Investors Service,
Fitch, Inc. and Standard & Poor's Rating Services.
Power has various lines of credit extended by banks to support the issuance
of letters of credit. As of March 31, 2001, letters of credit were issued in the
amount of approximately $90 million.
Energy Holdings
On March 31, 2001, Energy Holdings had two separate senior revolving credit
facilities with a syndicate of banks; a $495 million five-year revolving credit
and letter of credit facility and a $165 million 364-day revolving credit
facility. The interest rate on these facilities is based on LIBOR and the
average borrowing rate at Energy Holdings' current rating level is 1.375% over
the one, three or six month LIBOR rate. The revolving credit facilities also
permit shorter-term base rate borrowings at the prime rate. The five-year
facility also permits up to $250 million of letters of credit to be issued. The
five-year facility matures on May 12, 2004 and the 364-day facility which
matured on May 9, 2001, was extended to May 8, 2002 and increased to $200
million with no other changes to the terms of the facility. At December 31,
2000, Energy Holdings had $329 million outstanding under the revolving credit
facilities.
In February 2001, Energy Holdings, in a private placement, issued $400
million of 8.625% Senior Notes due 2008. The net proceeds from the sale were
used for repayment of the revolving credit facilities. Energy Holdings plans to
file a registration statement with the SEC relating to an exchange offer for, or
the resale of, these Senior Notes in 2001. On March 31, 2001, Energy Holdings
had no outstanding balances under its existing revolving credit facilities.
In March 2001, $160 million of non-recourse bank debt originally incurred
to fund a portion of the purchase price of Global's interest in Chilquinta
Energia, S.A. was refinanced. The private placement by offering of senior
secured notes was structured in two tranches: $60 million due 2008 at an
interest rate of 6.47% and $100 million due 2011 at an interest rate of 6.62%.
Accounting Matters
In July 2000, the Emerging Issues Task Force (EITF) 99-19, "Reporting
Revenue Gross as a Principal versus Net as an Agent" (EITF 99-19), provided
guidance on the issue of whether a company should report revenue based on the
gross amount billed to the customer or the net amount retained. The guidance
states that whether a company should recognize revenue based on the gross amount
billed or the net retained requires significant judgment, which depends on the
relevant facts and circumstances. In the first quarter of 2001, based on the
analysis and interpretation of EITF 99-19, PSEG reported all the revenues and
cost of goods sold on a gross basis for the energy related transactions. The
prior year financial statements for PSEG and its subsidiaries have been restated
for comparability purposes.
The Financial Accounting Standards Board (FASB) issued Statement of
Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative
Instruments and Hedging Activities, as amended, which became effective on
January 1, 2001. Under SFAS 133, certain contracts that were not formerly
considered derivatives may now meet the definition of a derivative. PSEG adopted
SFAS 133 effective January 1, 2001. See Notes 2 and 9 of Notes to the
Consolidated Financial Statements.
Foreign Operations
As of March 31, 2001, Global and Resources had approximately $2.023 billion
and $1.210 billion, respectively, of international assets. As of March 31, 2001,
foreign assets represented 59% of Energy Holdings' consolidated assets and the
revenues related to those foreign assets contributed 23% to consolidated
revenues for the quarter ended March 31, 2001. For discussion of Global's
foreign currency risk, see Note 6. Financial Instruments and Risk Management.
In April 2001, Global announced that the PPN Generation Station located in
India began commercial operations. The 330 MW combined-cycle plant is currently
being run on naphtha and will switch to a mixture of naphtha and natural gas as
offshore gas wells are completed. The Tamil Nadu Electricity Board will purchase
the entire output of the plant under a PPA.
Forward Looking Statements
Except for the historical information contained herein, certain of the
matters discussed in this report 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
"will", "anticipate", "intend", "estimate", "believe", "expect", "plan",
"hypothetical", "potential", variations of such words and similar expressions
are intended to identify forward-looking statements. PSEG and its subsidiaries
undertake no obligation to publicly update or revise any forward-looking
statements, whether as a result of new information, future events or otherwise.
The following review of factors should not be construed as exhaustive or as any
admission regarding the adequacy of disclosures made by PSEG and its
subsidiaries prior to the effective date of the Private Securities Litigation
Reform Act of 1995.
In addition to any assumptions and other factors referred to specifically
in connection with such forward-looking statements, factors that could cause
actual results to differ materially from those contemplated in any
forward-looking statements include, among others, the following: deregulation
and the unbundling of energy supplies and services and the establishment of a
competitive energy marketplace for products and services; managing rapidly
changing wholesale energy trading operations in conjunction with electricity and
gas production, transmission and distribution systems; managing foreign
investments and electric generation and distribution operations in locations
outside of the traditional utility service territory; political and foreign
currency risks; an increasingly competitive energy marketplace; sales retention
and growth potential in a mature PSE&G service territory; ability to complete
development or acquisition of current and future investments; partner and
counterparty risk; exposure to market price fluctuations and volatility of fuel
and power supply, power output, marketable securities, among others; ability to
obtain adequate and timely rate relief, cost recovery, and other necessary
regulatory approvals; Federal, state and foreign regulatory actions; regulatory
oversight with respect to utility and non-utility affiliate relations and
activities; operating restrictions, increased cost and construction delays
attributable to environmental regulations; nuclear decommissioning and the
availability of storage facilities for spent nuclear fuel; licensing and
regulatory approval necessary for nuclear and other operating stations; the
ability to economically and safely operate nuclear facilities in accordance with
regulatory requirements; environmental concerns; and market risk and debt and
equity market concerns associated with these issues.
ITEM 3. QUALITATIVE AND QUANTITATIVE
DISCLOSURES ABOUT MARKET RISK
The market risk inherent in PSEG's market risk sensitive instruments and
positions is the potential loss arising from adverse changes in commodity
prices, pollution credits, equity security prices, interest rates and foreign
currency exchange rates as discussed below. PSEG's policy is to use derivatives
to manage risk consistent with its business plans and prudent practices. PSEG
has a Risk Management Committee comprised of executive officers which utilizes
an independent risk oversight function to ensure compliance with corporate
policies and prudent risk management practices.
PSEG is exposed to credit losses in the event of non-performance or
non-payment by counterparties. PSEG also has a credit management process which
is used to assess, monitor and mitigate counterparty exposure for PSEG and its
subsidiaries. In the event of non-performance or non-payment by a major
counterparty, there may be a material adverse impact on PSEG's and its
subsidiaries' financial condition, results of operations or net cash flows. For
discussion of interest rates and Energy Holdings' commodity-related instruments,
equity securities and foreign currency risks, see Note 6. Financial Instruments
and Risk Management of Notes.
Commodity-Related Instruments
The availability and price of energy commodities are subject to
fluctuations from factors such as weather, environmental policies, changes in
supply and demand and state and Federal regulatory policies. To reduce price
risk caused by market fluctuations, PSEG's subsidiaries enter into derivative
contracts, including forwards, futures, swaps and options with approved
counterparties, to hedge its anticipated demand. These contracts, in conjunction
with owned electric generating capacity and physical gas supply contracts, are
designed to cover estimated electric and gas customer commitments.
PSEG uses a value-at-risk model to assess the market risk of its commodity
business. This model includes fixed price sales commitments, owned generation,
native load requirements, physical and financial contracts. Value-at-risk
represents the potential gains or losses for instruments or portfolios due to
changes in market factors, for a specified time period and confidence level.
PSEG estimates value-at-risk across its commodity business using a model with
historical volatilities and correlations.
The measured value-at-risk using a variance/co-variance model with a 95%
confidence level over a one-week time horizon at March 31, 2001 was
approximately $16 million, compared to the December 31, 2000 level of $19
million. PSEG's calculated value-at-risk represents an estimate of the potential
change in the value of its portfolio of physical and financial derivative
instruments. These estimates, however, are not necessarily indicative of actual
results, which may differ due to the fact that actual market rate fluctuations
may differ from forecasted fluctuations and due to the fact that the portfolio
of hedging instruments may change over the holding period.
Foreign Currencies--Energy Holdings
For discussion of foreign currency risks, see Note 6. Financial Instruments
and Risk Management of Notes.
- - --------------------------------------------------------------------------------
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
- - --------------------------------------------------------------------------------
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
Certain information reported under Item 3 of Part I of Public Service
Enterprise Group Incorporated's (PSEG), Annual Reports on Form 10-K is updated
below.
(1) Form 10-K, pages 11, 32, 64 and 65. See pages XX and XX. Appeals of the
BPUs Final Order and Finance Order in the Energy Master Plan Proceedings.
Docket Nos. C-1263-99, C-1265-99 and C-1413-99.
ITEM 4. SUBMISSION OF MATTERS TO
A VOTE OF SECURITY HOLDERS
PSEG's Annual Meeting of Stockholders was held on April 17, 2001. Proxies
for the meeting were solicited pursuant to Regulation 14A under the Securities
Act of 1934. There was no solicitation of proxies in opposition to management's
nominees as listed in the proxy statement and all of management's nominees were
elected to the Board of Directors. Details of the voting are provided below:
Votes Votes
For Withheld
-------------- --------------
Proposal 1 - Election of Directors
Class II - Term expiring 2004
Albert R. Gamper, Jr. 167,092,230 2,138,442
Richard J. Swift 167,465,857 2,040,611
Votes Votes
For Against Abstentions
-------------- -------------- ---------------
Proposal 2 - Ratification of the Appointment of
Deloitte & Touche LLP as Independent Auditors for 2001 167,465,857 783,811 1,287,890
With respect to Proposal 2, abstentions are not counted in the vote totals
and, therefore, have no effect on the vote.
ITEM 5. OTHER INFORMATION
Certain information reported under PSEG's 2000 Annual Report to the SEC is
updated below. References are to the related pages on the Form 10-K as printed
and distributed.
Gas Contract Transfer
Form 10-K, page 12. On March 16, 2001, the New Jersey Ratepayer Advocate
(RPA) filed a motion to dismiss this case. The motion is pending before the
Administrative Law Judge. At a hearing held on April 16, 2001, PSE&G presented a
Stipulation of Settlement. PSE&G is negotiating to have additional parties
execute the Stipulation. The Administrative Law Judge established a litigation
schedule through June 6, 2001 at which the hearings are expected to close.
Levelized Gas Adjustment Clause (LGAC)
Form 10-K, page 13. On March 30, 2001 the BPU issued its written Order
approving a 2% increases for PSE&G in each month from April 2001 to July 2001
and providing for recovery with interest of PSE&G's actual underrecovery balance
as of October 31, 2001 over a three-year period beginning on December 1, 2001.
The new rates were effective on April 1, 2001.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(A) A listing of exhibits being filed with this document is as follows:
Exhibit Number Document
-------------- ---------------------------------------------------------
12 Computation of Ratios of Earnings to Fixed Charges (PSEG)
(B) Reports on Form 8-K
Date of Report Items Reported
--------------- --------------
March 14, 2001 Item 5
SIGNATURES
Pursuant to the requirements 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.
PUBLIC SERVICE ENTERPRISE GROUP INCORPORATED
(Registrant)
By: Patricia A. Rado
-------------------------------------------------
Patricia A. Rado
Vice President and Controller
(Principal Accounting Officer)
Date: May 15, 2001