FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549-1004
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2002
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OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
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Commission Registrant; State of Incorporation; I.R.S. Employer
File Number Address; and Telephone Number Identification No.
- ----------- ----------------------------------- ------------------
1-5324 NORTHEAST UTILITIES 04-2147929
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(a Massachusetts voluntary association)
174 Brush Hill Avenue
West Springfield, Massachusetts 01090-2010
Telephone: (413) 785-5871
0-11419 THE CONNECTICUT LIGHT AND POWER COMPANY 06-0303850
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(a Connecticut corporation)
107 Selden Street
Berlin, Connecticut 06037-1616
Telephone: (860) 665-5000
1-6392 PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE 02-0181050
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(a New Hampshire corporation)
1000 Elm Street
Manchester, New Hampshire 03105-0330
Telephone: (603) 669-4000
0-7624 WESTERN MASSACHUSETTS ELECTRIC COMPANY 04-1961130
--------------------------------------
(a Massachusetts corporation)
174 Brush Hill Avenue
West Springfield, Massachusetts 01090-2010
Telephone: (413) 785-5871
Indicate by check mark whether the registrants (1) have filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrants were required to file such reports), and (2) have been subject to
such filing requirements for the past 90 days.
Yes X No
--- ---
Indicate the number of shares outstanding of each of the issues' classes of
common stock, as of the latest practicable date:
Company - Class of Stock Outstanding at April 30, 2002
- ------------------------ -----------------------------
Northeast Utilities
Common shares, $5.00 par value 129,559,833 shares
The Connecticut Light and Power Company
Common stock, $10.00 par value 7,584,884 shares
Public Service Company of New Hampshire
Common stock, $1.00 par value 388 shares
Western Massachusetts Electric Company
Common stock, $25.00 par value 509,696 shares
GLOSSARY OF TERMS
The following is a glossary of frequently used abbreviations or acronyms that
are found throughout this report:
COMPANIES
- ---------
CL&P........................... The Connecticut Light and Power Company
DNCI........................... Dominion Nuclear Connecticut, Inc.
NAEC........................... North Atlantic Energy Corporation
NGC............................ Northeast Generation Company
NU or the company.............. Northeast Utilities
NU system...................... The Northeast Utilities system companies,
including NU and its wholly owned
operating subsidiaries: CL&P, PSNH,
WMECO, NAEC, and Yankee Gas
PSNH........................... Public Service Company of New Hampshire
Select Energy.................. Select Energy, Inc.
WMECO.......................... Western Massachusetts Electric Company
Yankee......................... Yankee Energy System, Inc.
Yankee Gas..................... Yankee Gas Services Company
NUCLEAR UNIT
Seabrook....................... Seabrook Unit No. 1, a 1,148 megawatt nuclear
electric generating unit completed in 1986;
Seabrook went into service in 1990.
REGULATORS
DPUC........................... Connecticut Department of
Public Utility Control
DTE............................ Massachusetts Department of
Telecommunications and Energy
NHPUC.......................... New Hampshire Public Utilities Commission
OTHER
EPS............................ Earnings per share
FASB........................... Financial Accounting Standards Board
FPPAC.......................... Fuel and purchased-power adjustment clause
kWh............................ Kilowatt-hour
MW............................. Megawatts
NU 2001 Form 10-K.............. The NU system combined 2001 Form 10-K as
filed with the Securities and Exchange
Commission
O&M............................ Operation and maintenance
SFAS........................... Statement of Financial Accounting Standards
Northeast Utilities and Subsidiaries
The Connecticut Light and Power Company and Subsidiaries
Public Service Company of New Hampshire and Subsidiaries
Western Massachusetts Electric Company and Subsidiary
TABLE OF CONTENTS
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Page
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Part I. Financial Information
Item 1. Financial Statements (Unaudited)
and
Item 2. Management's Discussion and
Analysis of Financial Condition
and Results of Operations
For the following companies:
Northeast Utilities and Subsidiaries
Consolidated Balance Sheets -
March 31, 2002 and December 31, 2001.................. 2
Consolidated Statements of Income -
Three Months Ended March 31, 2002 and 2001............ 4
Consolidated Statements of Cash Flows -
Three Months Ended March 31, 2002 and 2001............ 5
Management's Discussion and Analysis of
Financial Condition and Results of Operations......... 6
Independent Accountants' Report....................... 21
Report of Independent Public Accountants.............. 22
The Connecticut Light and Power Company
and Subsidiaries
Consolidated Balance Sheets -
March 31, 2002 and December 31, 2001.................. 24
Consolidated Statements of Income -
Three Months Ended March 31, 2002 and 2001............ 26
Consolidated Statements of Cash Flows -
Three Months Ended March 31, 2002 and 2001............ 27
Management's Discussion and Analysis of
Financial Condition and Results of Operations......... 28
Public Service Company of New Hampshire
and Subsidiaries
Consolidated Balance Sheets -
March 31, 2002 and December 31, 2001.................. 32
Consolidated Statements of Income -
Three Months Ended March 31, 2002 and 2001 ........... 34
Consolidated Statements of Cash Flows -
Three Months Ended March 31, 2002 and 2001............ 35
Management's Discussion and Analysis of
Financial Condition and Results of Operations......... 36
Western Massachusetts Electric Company and Subsidiary
Consolidated Balance Sheets -
March 31, 2002 and December 31, 2001.................. 40
Consolidated Statements of Income -
Three Months Ended March 31, 2002 and 2001............ 42
Consolidated Statements of Cash Flows -
Three Months Ended March 31, 2002 and 2001............ 43
Management's Discussion and Analysis of
Financial Condition and Results of Operations......... 44
Notes to Financial Statements
(unaudited - all companies)................................ 47
Part II. Other Information
Item 1. Legal Proceedings................................ 61
Item 6. Exhibits and Reports on Form 8-K................. 63
Signatures........................................................... 65
NORTHEAST UTILITIES AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
-------------- --------------
(Thousands of Dollars)
ASSETS
- ------
Current Assets:
Cash and cash equivalents.............................. $ 106,810 $ 96,658
Investments in securitizable assets.................... 40,334 36,367
Receivables, net....................................... 733,998 831,221
Unbilled revenues...................................... 121,385 126,398
Fuel, materials and supplies, at average cost.......... 108,884 108,516
Special deposits....................................... 26,605 13,036
Prepayments and other.................................. 152,405 126,233
-------------- --------------
1,290,421 1,338,429
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Property, Plant and Equipment:
Electric utility....................................... 5,791,334 5,729,181
Gas utility............................................ 651,607 634,884
Competitive energy..................................... 1,007,887 1,006,971
Other.................................................. 198,059 195,741
-------------- --------------
7,648,887 7,566,777
Less: Accumulated provision for depreciation......... 3,454,054 3,418,577
-------------- --------------
4,194,833 4,148,200
Construction work in progress.......................... 293,486 289,889
Nuclear fuel, net...................................... 29,369 32,564
-------------- --------------
4,517,688 4,470,653
-------------- --------------
Deferred Debits and Other Assets:
Regulatory assets ..................................... 3,182,817 3,287,537
Goodwill and other purchased intangible assets, net.... 334,995 335,447
Prepaid pension........................................ 249,923 232,398
Nuclear decommissioning trusts, at market.............. 62,107 61,713
Other ................................................. 511,606 468,007
-------------- --------------
4,341,448 4,385,102
-------------- --------------
Total Assets............................................. $ 10,149,557 $ 10,194,184
============== ==============
</Table>
The accompanying notes are an integral part of these financial statements.
NORTHEAST UTILITIES AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
-------------- --------------
(Thousands of Dollars)
LIABILITIES AND CAPITALIZATION
- ------------------------------
Current Liabilities:
Notes payable to banks................................. $ 230,000 $ 290,500
Long-term debt - current portion....................... 313,536 50,462
Accounts payable....................................... 502,199 622,320
Accrued taxes.......................................... 58,434 26,203
Accrued interest....................................... 68,584 35,659
Other.................................................. 163,473 161,277
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1,336,226 1,186,421
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Rate Reduction Bonds..................................... 2,051,807 2,018,351
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Deferred Credits and Other Liabilities:
Accumulated deferred income taxes...................... 1,479,382 1,491,394
Accumulated deferred investment tax credits............ 116,312 120,071
Deferred contractual obligations....................... 206,696 216,566
Other.................................................. 680,657 634,985
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2,483,047 2,463,016
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Capitalization:
Long-Term Debt......................................... 2,023,432 2,292,556
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Preferred Stock........................................ 116,200 116,200
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Common shareholders' equity:
Common shares, $5 par value - authorized
225,000,000 shares; 149,116,706 shares issued and
129,477,227 shares outstanding in 2002 and
148,890,640 shares issued and 130,132,136 shares
outstanding in 2001................................. 745,584 744,453
Capital surplus, paid in............................. 1,111,440 1,107,609
Deferred contribution plan - employee stock
ownership plan..................................... (98,802) (101,809)
Retained earnings.................................... 680,934 678,460
Accumulated other comprehensive loss................. (3,458) (32,470)
Treasury stock....................................... (296,853) (278,603)
-------------- --------------
Common Shareholders' Equity............................ 2,138,845 2,117,640
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Total Capitalization..................................... 4,278,477 4,526,396
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Commitments and Contingencies (Note 2)
Total Liabilities and Capitalization..................... $ 10,149,557 $ 10,194,184
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</Table>
The accompanying notes are an integral part of these financial statements.
NORTHEAST UTILITIES AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
<Table>
<Caption>
Three Months Ended
March 31,
--------------------------------
2002 2001
-------------- ---------------
(Thousands of Dollars,
except share information)
Operating Revenues..................................... $ 1,910,683 $ 1,800,544
-------------- --------------
Operating Expenses:
Operation -
Fuel, purchased and net interchange power......... 1,352,837 1,130,839
Other............................................. 198,031 218,928
Maintenance.......................................... 52,312 88,681
Depreciation......................................... 47,881 60,629
Amortization......................................... 70,738 719,856
Taxes other than income taxes........................ 74,598 75,887
Gain on sale of utility plant........................ - (653,872)
-------------- --------------
Total operating expenses......................... 1,796,397 1,640,948
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Operating Income....................................... 114,286 159,596
Other (Loss)/Income, Net............................... (13,997) 157,198
-------------- --------------
Income Before Interest and Income Tax Expense.......... 100,289 316,794
-------------- --------------
Interest Expense:
Interest on long-term debt........................... 34,548 43,668
Interest on rate reduction bonds..................... 29,562 -
Other interest....................................... 2,777 23,527
-------------- --------------
Interest expense, net........................... 66,887 67,195
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Income Before Income Tax Expense....................... 33,402 249,599
Income Tax Expense..................................... 13,370 112,300
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Income Before Preferred Dividends of Subsidiaries...... 20,032 137,299
Preferred Dividends of Subsidiaries.................... 1,390 2,704
-------------- --------------
Income Before Cumulative Effect of Accounting Change... 18,642 134,595
Cumulative effect of accounting change, net
of tax benefit of $14,908............................ - (22,432)
-------------- --------------
Net Income............................................. $ 18,642 $ 112,163
============== ==============
Basic and Fully Diluted Earnings Per Common Share:
Income Before Cumulative Effect of Accounting Change... $ 0.14 $ 0.93
Cumulative effect of accounting change,
net of tax benefit................................. - (0.15)
-------------- --------------
Basic and Fully Diluted Earnings Per Common Share...... $ 0.14 $ 0.78
============== ==============
Basic Common Shares Outstanding (average).............. 129,504,005 143,912,698
============== ==============
Fully Diluted Common Shares Outstanding (average)...... 129,754,946 144,314,339
============== ==============
</Table>
The accompanying notes are an integral part of these financial statements.
NORTHEAST UTILITIES AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
<Table>
<Caption>
Three Months Ended
March 31,
--------------------------------
2002 2001
-------------- ---------------
(Thousands of Dollars)
Operating Activities:
Income before preferred dividends of subsidiaries........... $ 20,032 $ 137,299
Adjustments to reconcile to net cash flows
provided by operating activities:
Depreciation.............................................. 47,881 60,629
Deferred income taxes and investment tax credits, net..... (22,803) (226,451)
Amortization.............................................. 70,738 719,856
Net amortization/(deferral) of recoverable energy costs... 22,053 (7,374)
Gain on sale of utility plant............................. - (678,884)
Cumulative effect of accounting change.................... - (22,432)
Net other sources/(uses) of cash.......................... 48,783 (83,749)
Changes in working capital:
Receivables and unbilled revenues, net.................... 102,235 (227,547)
Fuel, materials and supplies.............................. (368) 69,516
Accounts payable.......................................... (120,122) 114,290
Accrued taxes............................................. 32,232 322,856
Investments in securitizable assets....................... (3,967) 11,715
Other working capital (excludes cash)..................... 24,288 40,229
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Net cash flows provided by operating activities............... 220,982 229,953
------------ -------------
Investing Activities:
Investments in plant:
Electric, gas and other utility plant..................... (97,200) (100,230)
Nuclear fuel.............................................. (164) (926)
------------ -------------
Cash flows used for investments in plant.................... (97,364) (101,156)
Investments in nuclear decommissioning trusts............... (393) (106,826)
Net proceeds from the sale of utility plant................. - 1,035,185
Buyout/buydown of IPP contracts............................. - (977,433)
Other investment activities, net............................ (43,761) (20,023)
------------ -------------
Net cash flows used in investing activities................... (141,518) (170,253)
------------ -------------
Financing Activities:
Issuance of common shares................................... 1,130 411
Repurchase of common shares................................. (18,250) -
Issuance of long-term debt.................................. - 265,663
Issuance of rate reduction bonds............................ 50,000 1,438,400
Retirement of rate reduction bonds.......................... (16,544) -
Net decrease in short-term debt............................. (60,500) (198,561)
Reacquisitions and retirements of long-term debt............ (7,410) (241,906)
Reacquisitions and retirements of preferred stock........... - (36,500)
Cash dividends on preferred stock........................... (1,390) (2,704)
Cash dividends on common shares............................. (16,171) (14,390)
Other financing activities, net............................. (177) 2,324
------------ -------------
Net cash flows (used in)/provided by financing activities..... (69,312) 1,212,737
------------ -------------
Net increase in cash and cash equivalents..................... 10,152 1,272,437
Cash and cash equivalents - beginning of period............... 96,658 200,017
------------ -------------
Cash and cash equivalents - end of period..................... $ 106,810 $ 1,472,454
============ =============
</Table>
The accompanying notes are an integral part of these financial statements.
NORTHEAST UTILITIES AND SUBSIDIARIES
Management's Discussion and Analysis of
Financial Condition and Results of Operations
This discussion should be read in conjunction with the consolidated
financial statements and footnotes in this Form 10-Q, the NU 2001 Form
10-K, current reports on Form 8-K dated January 22, 2002, January 30,
2002, March 15, 2002, and April 23, 2002, and the current report on
Form 8-K/A dated March 15, 2002.
FINANCIAL CONDITION
Overview
Northeast Utilities and subsidiaries (NU or the company) reported
first quarter 2002 earnings of $18.6 million, or $0.14 per share on a
fully diluted basis, compared with earnings of $112.2 million, or
$0.78 per share on a fully diluted basis, during the same period of
2001. During both periods, NU's results were affected significantly by
nonrecurring items.
During the first quarter of 2002, NU recorded an after-tax charge of
$10 million, or $0.08 per share, associated with: 1) the write-down
of its investment in NEON Communications, Inc. (NEON), a provider of
high-bandwidth fiber optic telecommunications services, of $8.5
million, or $0.07 per share, after-tax and; 2) an additional after-tax
write-down of $1.5 million or $0.01 per share related to another
investment. During the first quarter of 2001, NU recorded an after-
tax gain of $124.8 million, or $0.87 per share, in connection with the
sale of the Millstone nuclear units to a subsidiary of Dominion
Resources, Inc., Dominion Nuclear Connecticut, Inc. (DNCI). During the
first quarter of 2001, NU also recorded an after-tax charge of $43.4
million, or $0.30 per share, associated with the forward repurchase of
NU common shares and an after-tax charge of $22.4 million, or $0.15
per share, as a result of the adoption of Statement of Financial
Accounting Standards (SFAS) No. 133, "Accounting for Derivative
Instruments and Hedging Activities," as amended.
Excluding the effects of those nonrecurring items, NU earned $28.6
million, or $0.22 per share on a fully diluted basis, during the first
quarter of 2002, compared with earnings of $53.2 million, or $0.36 per
share on a fully diluted basis, during the same period of 2001.
Revenues during the first quarter of 2002 increased to $1.9 billion
from $1.8 billion during the same period of 2001, primarily due to
higher sales at NU's competitive energy subsidiaries.
The decline in NU's earnings, excluding the effects of nonrecurring
items, was primarily due to the decline in earnings at NU's regulated
electric operating companies as a result of much milder weather during
the first quarter of 2002, compared with the same period of 2001, and
the effects of industry restructuring, primarily in New Hampshire.
Earnings before preferred dividends of subsidiaries at The Connecticut
Light and Power Company (CL&P) totaled $21.7 million during the first
quarter of 2002, compared with $38.3 million during the first quarter
of 2001. Earnings before preferred dividends of subsidiaries at Public
Service Company of New Hampshire (PSNH) declined to $11.7 million
during the first quarter of 2002, compared with $28.4 million during
the first quarter of 2001.
Earnings at Yankee Energy System, Inc. (Yankee) totaled $12.6 million
during the first quarter of 2002, compared with $15.6 million during
the same period of 2001. The decline in Yankee's earnings was
attributable to a 17.5 percent decline in firm natural gas volumes,
partially offset by lower operating expenses. The decline in sales at
Yankee was partially offset by the $7.5 million decrease in
amortization expense related to the goodwill created in conjunction
with NU's merger with Yankee, upon the adoption of SFAS No. 142,
"Goodwill and Other Intangible Assets," on January 1, 2002.
Also negatively impacting performance in 2002 were losses of $21.6
million at NU's competitive energy subsidiaries during the first three
months of 2002, compared with losses of $4.2 million during the same
period of 2001, excluding the effect of the adoption of SFAS No. 133.
The performance at the competitive energy subsidiaries was primarily
due to: 1) mild dry weather, which resulted in a decline in wholesale
and retail electric and natural gas sales; 2) a decline in
conventional hydroelectric production, and; 3) to an increase in
natural gas prices in March 2002, which had a detrimental effect on
the company's trading portfolio.
Partially offsetting the aforementioned performance, earnings before
preferred dividends of subsidiaries at Western Massachusetts Electric
Company (WMECO) increased to $6.9 million during the first quarter of
2002, compared with $3.3 million during the same period of 2001,
primarily as a result of costs WMECO incurred in 2001 related to an
extended refueling outage at Millstone 3.
Also partially offsetting those factors was a significant decline in
NU's outstanding shares. NU repurchased approximately 850,000 shares
in the first quarter of 2002 and repurchased approximately 14.3
million shares during the last nine months of 2001. The positive
impact on NU's earnings per share as a result of these repurchases was
$0.02 per share during the first quarter of 2002, as compared to the
same period of 2001.
Also offsetting the mild dry weather were lower operation and
maintenance expenses unrelated to fuel and purchased power, which
declined to $250.3 million during the first quarter of 2002, compared
with $307.6 million during the first quarter of 2001. This reduction
was primarily due to the sale of Millstone, as Millstone 3 underwent
an extended refueling outage during the first quarter of 2001.
Future Outlook
Despite the below-budget results of the first quarter of 2002, NU
believes it can earn between $1.40 to $1.65 per share in 2002,
excluding certain nonrecurring items: 1) the $10 million write-off
related to NEON and another investment, and; 2) expected consolidated
after-tax gains of between $25 million and $30 million, related to the
proposed sale of the NU system's 40.04 percent ownership interest in
the Seabrook nuclear unit. Achieving that earnings range will depend
largely on continued expense control, more seasonal weather patterns,
and improved performance at NU's competitive businesses.
On April 15, 2002, CL&P, North Atlantic Energy Corporation (NAEC) and
certain other joint owners reached an agreement to sell approximately
88.2 percent of the Seabrook nuclear unit to a subsidiary of the FPL
Group, Inc. (FPL) for $836.6 million. The aforementioned gains relate
to an agreement with an unaffiliated company in connection with the
sale of their share of Seabrook and to the elimination of certain
reserves previously set aside for the abandoned Seabrook 2 nuclear
unit. Management anticipates these gains will be recognized during
2002.
Another primary variable in NU's earnings range of $1.40 to $1.65 per
share for 2002 is the result of the Connecticut Department of Public
Utility Control's (DPUC) examination of effective retail electric
competition in Connecticut and the viability of CL&P's standard offer
service supply contracts. The higher end of the 2002 earnings range
is contingent upon an increase of $0.01 per kWh in Select Energy's
revenues commencing July 1, 2002, as a result of this examination.
In addition, management is in the process of the first assessment of
impairment of goodwill under SFAS No. 142, "Goodwill and Other
Intangible Assets," and expects to complete this assessment by the
June 30, 2002, deadline. Upon adoption of the impairment testing
rules under SFAS No. 142, there may be a cumulative effect of an
accounting change which management has not evaluated at this time. For
further information regarding the first assessment of impairment of
goodwill under SFAS No. 142, see note 1C, "Summary of Significant
Accounting Policies - New Accounting Standards," to the consolidated
financial statements.
Liquidity
On January 30, 2002, PSNH Funding LLC 2, a subsidiary of PSNH, sold
$50 million of additional rate reduction bonds, at an interest rate of
4.58 percent. The bonds, which were rated AAA by three credit rating
agencies, have a scheduled maturity date of February 1, 2008. PSNH
used the proceeds to repay short-term debt that was incurred to buyout
a purchased-power contract in December 2001.
On April 4, 2002, NU closed on the refinancing of $263 million of
senior unsecured notes. The notes bear interest at 7.25 percent and
mature on April 1, 2012. Proceeds from the refinancing were used to
redeem a similar amount of variable rate notes that were issued on
February 28, 2001.
In the first quarter of 2002, NU repurchased approximately 850,000 of
its common shares at an average share price of $18.46. As of
March 31, 2002, NU can repurchase approximately 10 million additional
shares by July 2003 under its existing board authorization.
NU expects to close on the sale of its 40.04 percent share of Seabrook
around the end of 2002. Of the approximately $400 million of total
cash proceeds NU expects to receive from the Seabrook sale, a portion
of these proceeds will be used to repay all $90 million of NAEC's
outstanding debt and return all NAEC's equity, which totaled $35.9
million as of March 31, 2002, to NU and pay between $100 million and
$120 million in taxes. Following the sale of NAEC's share of
Seabrook, the Seabrook Power Contracts between PSNH and NAEC will be
terminated. PSNH will use these proceeds to more quickly amortize
stranded costs. The net gain from the sale related to CL&P's share of
Seabrook primarily will be used to offset stranded costs and any cash
received by CL&P will be used to meet its capital requirements.
NU's net cash flows provided by operating activities declined slightly
to $221 million in the first quarter of 2002, compared with $230
million during the same period of 2001. In the first quarter of 2002,
cash flows provided by operating activities decreased primarily due to
a $117.3 million decrease in income before preferred dividends of
subsidiaries, primarily due to the gains related to the sale of
Millstone which occurred in the first quarter of 2001. Increased
payments made on accounts payable balances, primarily at the
competitive energy subsidiaries, in the first quarter of 2002 also
decreased cash flows provided by operations. These decreases were
offset by increased receipts received on accounts receivable balances
during the first quarter of 2002, primarily at the competitive energy
subsidiaries, compared with the same period of 2001.
Financing activities were significantly reduced in the first quarter
of 2002, as compared to the same quarter of 2001, primarily due to the
issuance of CL&P rate reduction certificates. The level of common
dividends totaled $16.2 million in the first quarter of 2002, compared
with $14.4 million during the same period of 2001. This increase was
a result of NU paying a $0.10 per share quarterly common dividend in
the first two quarters of 2001 and a $0.125 per share quarterly common
dividend in the last two quarters of 2001 and the first quarter of
2002.
On March 28, 2002, NU paid a quarterly dividend of $0.125 per share.
On April 9, 2002, NU's Board of Trustees approved payment of another
cash dividend of $0.125 per share on June 28, 2002, to shareholders of
record as of June 1, 2002. NU anticipates increasing its dividend by
approximately 10 percent annually and eventually paying out
approximately 50 percent of the aggregate earnings of its regulated
companies in the form of common dividends. Such a program will be
dependent upon numerous factors, including NU's ability to meet
earnings targets and the judgment of its Board of Trustees at the
time.
Helping to finance the aforementioned share repurchases and common
dividend were the first quarter 2002 payments of $15 million of common
dividends from CL&P, $16.8 million from PSNH and $4 million from
WMECO, based on the aggregate earnings of these subsidiaries.
Competitive Energy Subsidiaries
NU's competitive energy subsidiaries had a loss of $21.6 million in
the first quarter of 2002, compared with a loss of $4.2 million before
the cumulative effect of an accounting change related to the adoption
of SFAS No. 133, as amended, in the first quarter of 2001.
Unconsolidated revenues for the competitive energy subsidiaries
totaled approximately $1 billion in the first quarter of 2002,
compared with $636.7 million in the first quarter of 2001. The
increased revenues are primarily the result of increased trading
volumes resulting in physical delivery of energy products and the
acquisition of Select Energy New York, Inc. (SENY). CL&P's standard
offer purchases from Select Energy, Inc. (Select Energy) represented
$158.5 million of total competitive energy subsidiaries' revenues in
the first quarter of 2002, compared with $171.1 million in the first
quarter of 2001. These amounts are eliminated in consolidation.
NU's competitive energy subsidiaries own 1,436 megawatts (MW) of
generation capacity, consisting of 1,289 MW at Northeast Generation
Company (NGC) and 147 MW at Holyoke Water Power Company (HWP). These
businesses also include wholesale and retail energy marketing
organizations and an expanding trading business. The energy marketing
organizations also buy and sell natural gas and other fuels. The
competitive energy subsidiaries also include Select Energy Services,
Inc., which performs energy management services for large industrial,
commercial and institutional facilities, including the United States
Department of Defense, and Northeast Generation Services Company,
which operates and maintains NGC's and HWP's generation assets and
provides third-party contracting services for power plants and large
industrial facilities.
One of management's primary goals in 2002 is to improve the results of
Select Energy's energy marketing and trading businesses. To manage
market risk, Select Energy has procured almost 100 percent of the
projected on-peak and the vast majority of the off-peak electricity
requirements needed to serve the CL&P standard offer service load. In
addition, management continues to work with state regulators to
increase CL&P's standard offer service price. Select Energy
management also continues to work with third parties to arrange new
profitable energy contracts to replace a number of wholesale contracts
that are in the process of expiring. Management also expects the
operations of SENY which was acquired by Select Energy in November
2001, to significantly increase its business in New York and to
generate positive net income in 2002.
Competitive Energy Subsidiaries' Market and Other Risks
NU's competitive energy subsidiaries, as major providers of
electricity and natural gas, are exposed to certain market risks
inherent in their business activities. The competitive energy
subsidiaries enter into contracts of varying lengths of time to buy
and sell energy commodities, primarily electricity, natural gas and
oil. Market risk represents the risk of loss that may impact the
companies' financial statements due to adverse changes in commodity
market prices.
A significant portion of the competitive energy subsidiaries wholesale
marketing business is energy provided to full requirements customers,
primarily regulated distribution companies. Under the contract terms
the company is required to provide the total energy requirement to the
customers load at all times.
The competitive energy subsidiaries manage their portfolio of
contracts and assets to maximize value and minimize associated risks.
The lengths of contracts to buy and sell energy vary in duration from
daily/hourly to several years. At any point in time, the portfolio
may be long (purchases exceed sales) or short (sales exceed
purchases). Portfolio and risk management disciplines are used to
manage exposures to market risks. Policies and procedures have been
established to manage these risks. At market spot prices in effect at
March 31, 2002, the portfolio had a positive mark-to-market position.
There is significant volatility in the energy commodities market. This
position fluctuates in value due to changes in energy prices in the
region and new transactions entered into during the period.
Select Energy also engages in the trading of commodity derivatives,
which are accounted for using the mark-to-market method under Emerging
Issues Task Force Issue No. 98-10, "Accounting for Energy Trading and
Risk Management Activities." All other nontrading transactions are
recognized when settled.
The company has policies and procedures requiring all trading
positions to be marked-to-market daily at the end of each trading day.
Controls are in place segregating responsibilities between individuals
actually trading (front office) and those verifying the trades (middle
office). The mark-to-market calculations are performed by individuals
in the middle office independent from the front office. All New York
Mercantile Exchange futures and options are marked to closing exchange
prices. Over-the-counter forwards and options are marked to the mid-point
of bid and ask quotes. In most cases there are multiple sources of
over-the-counter and broker quotes. Options, for which specific quotes
are not available, are marked-to-market using a forward volatility curve
derived from other options for which quotes are available.
As of and for the three months ended March 31, 2002, the sources of
the fair value of these trading activities and the change in fair
value of these trading activities are as follows:
- -------------------------------------------------------------------------------
(Millions of Dollars) Fair Value of Contracts at March 31, 2002
- -------------------------------------------------------------------------------
Maturity Maturity of Maturity in Total
Less than One to Four Excess of Fair
Sources of Fair Value One Year Years Four Years Value
- -------------------------------------------------------------------------------
Prices actively quoted $(14.3) $ 5.2 $ - $(9.1)
Prices provided by
external sources 9.7 39.2 20.8 69.7
Prices based on
model or other
valuation method (2.1) (1.0) - (3.1)
- -------------------------------------------------------------------------------
Totals $ (6.7) $43.4 $20.8 $57.5
- -------------------------------------------------------------------------------
- ---------------------------------------------------------------
(Millions of Dollars) Total Fair Value
- ---------------------------------------------------------------
Fair value of contracts
outstanding at the beginning
of the period (January 1, 2002) $56.4
Contracts realized or otherwise
settled during the period 1.3
Fair value of new contracts when
entered into during the period 11.6
Changes in fair values
attributable to changes in
valuation techniques and
assumptions (12.0)
Changes in fair value of
contracts that existed at the
beginning of the period 0.2
- ---------------------------------------------------------------
Fair value of contracts
outstanding at the end
of the period (March 31, 2002) $57.5
- ---------------------------------------------------------------
During the first quarter of 2002, the competitive energy subsidiaries
terminated certain long-term energy contracts. Coincident with the
termination, new contracts for different energy products were entered
into. These new contracts are derivatives and had a positive mark-to-
market of $11.6 million as of March 31, 2002.
For further information see Note 3, "Market Risk and Risk Management
Instruments," and Note 4, "Comprehensive Income," to the consolidated
financial statements.
Business Development and Capital Expenditures
NU's capital expenditures totaled $97.2 million during the first quarter
of 2002, compared with $100.2 million during the same period of 2001.
The NU system companies currently forecast construction expenditures of
up to $593 million for the year 2002, including expenditures of approximately
$70 million for the construction of a new transmission line facility between
Norwalk, Connecticut and Long Island, New York. However, as siting
applications to build that transmission line facility have not yet been filed
and contracts have not yet been signed with potential users, it is possible
that NU's overall construction expenditures for 2002 will be less than
current projections.
Beyond its budgeted construction program, NU continues to pursue additional
investments in both the regulated and competitive energy businesses in the
Northeast United States or other strategic initiatives from time to time.
In May 2002, the Connecticut Legislature approved a moratorium that could
affect the timing of some of the NU system's electric transmission
construction projects in southwest Connecticut. The moratorium, if signed
by the Governor, would prevent the Connecticut Siting Council (CSC) from
issuing a final decision on a 345,000 volt transmission line CL&P has
proposed building between Bethel, Connecticut and Norwalk, Connecticut
until at least February 1, 2003. The legislation would also create two task
forces, one to prepare an environmental assessment and plan for energy
projects beneath Long Island Sound and the other to examine issues
associated with distributed generation and electric transmission lines.
An application to construct the overhead line at an estimated cost of $135
million was filed with the CSC in October 2001. The moratorium would not
affect the rebuilding of a 138,000 volt undersea cable between
Norwalk, Connecticut and Northport - Long Island, New York. CL&P and
the Long Island Power Authority would share the estimated $80 million
cost of replacing the cable, which CL&P hopes to complete by the
summer of 2003.
Restructuring and Rate Matters
Connecticut - CL&P: On September 28, 2001, the DPUC ordered a $21.3 million
annual reduction in CL&P's System Benefits Charge as a result of a sharp
reduction in decommissioning collections and an equal increase in the
Competitive Transition Assessment. These changes were effective on March 1,
2002. Also, on July 26, 2001, the DPUC authorized CL&P to assess a charge
of approximately $0.002 per kilowatt-hour (kWh) from August 2001 through
December 2003 to collect approximately $98.5 million of deferred fuel costs.
The net result of these decisions was a reduction in CL&P's pretax earnings
of $21.1 million beginning June 20, 2001, an acceleration of CL&P's
recovery of stranded costs in 2002 and 2003, and further enhancement of
CL&P's cash flows.
On September 27, 2001, CL&P filed its application with the DPUC for
approval of the disposition of the proceeds from the sale of the
Millstone units to DNCI. This application described and requested
DPUC approval for CL&P's treatment of its share of the proceeds from
the sale. A decision from the DPUC is expected in the second quarter
of 2002.
On November 23, 2001, CL&P petitioned the DPUC to adjust its stranded
costs to account for the announced sale of the Vermont Yankee nuclear
unit to an unaffiliated company. CL&P has requested that the DPUC
review and approve its petition expeditiously, to enable the sale to
be completed by July 2002. However, other regulatory approvals are
required to enable the completion of the sale by July 2002.
Since retail competition began in Connecticut in 2000, an extremely
small number of CL&P customers have opted to choose their retail
supplier. Currently, virtually all of CL&P's customers are procuring
their electricity through CL&P's standard offer service. Through
December 2003, 50 percent of CL&P's standard offer service
requirements will be purchased from Select Energy with the remaining
50 percent being purchased from two unaffiliated companies. On
November 18, 2001, at the request of one of the unaffiliated
companies, CL&P filed a request with the DPUC to raise the standard
offer service rate from an average of $0.0495 per kWh to $0.0595 per
kWh to help promote competition in advance of the January 1, 2004,
termination of the standard offer service period and to provide
financial relief to the standard offer suppliers. In December 2001,
the DPUC rejected CL&P's request, but opened two new dockets to
examine the absence of effective retail electric competition in
Connecticut and the viability of its standard offer service supply
contracts. The first docket culminated in a joint study report issued
in a decision by the DPUC on February 15, 2002, which provided the
DPUC's and the Office of Consumer Counsel's findings on how to best
structure default service and other issues related to electric
industry restructuring. The second of the two dockets focused on the
viability of the standard offer service contracts. The DPUC held
hearings on the second docket in February 2002. A decision in this
docket, which is expected in the second quarter of 2002, could lead to
the re-opening of CL&P's standard offer docket.
Connecticut - Yankee Gas: On July 24, 2001, Yankee Gas Services
Company (Yankee Gas) filed a rate application with the DPUC requesting
a 7.64 percent or $29.2 million increase in rates to fund system
reliability projects and a proposed expansion of its distribution
system. On January 30, 2002, the DPUC issued a final decision which
ordered a $4 million rate decrease effective March 1, 2002. This rate
decrease was, in part, based upon adjustments that Yankee Gas had
agreed to during the proceedings. The final decision, however,
approved partially or fully many of the proposals made by Yankee Gas
in its filing. The decision endorses Yankee Gas' distribution system
expansion plan, subject to annual reviews, and approves, with some
conditions, its ratemaking recovery mechanism (Infrastructure
Expansion Rate Mechanism). The final decision also authorizes an 11
percent return on equity for Yankee Gas and a sharing formula for
earnings above that level from 2002 through 2005. Subsequent to the
final decision, the effective date of the rate decrease was delayed
until April 1, 2002.
During the first quarter of 2002, the DPUC opened a docket on its own
motion to review Yankee Gas' earnings as a result of the quarterly
earnings reports filed for the 12 months ended September 30, 2001, and
December 31, 2001. Yankee Gas filed a motion in April 2002,
indicating that the docket should be terminated as a result of the
DPUC's decision in Yankee Gas' rate application on January 30, 2002,
which reduced rates effective April 1, 2002, and approved an earnings
sharing mechanism. On May 9, 2002, the DPUC issued a draft decision
which granted Yankee Gas' motion to terminate this docket as there is
no basis upon which to conduct another proceeding to evaluate Yankee
Gas' earnings. A final decision is scheduled to be issued on May 15,
2002.
On January 22, 2002, Yankee Gas filed an application with the DPUC for
approval of a special rate contract to supply firm transportation
service to a new 544 MW natural gas-fired electric generation station
expected to be operational in the summer of 2003. Under the contract,
Yankee Gas will construct the required distribution facilities that
will interconnect the plant with interstate natural gas pipeline
facilities and will provide firm transportation service to the plant
under a special contract rate. A final decision approving the
contract was received on May 8, 2002.
On October 23, 2001, the DPUC opened a second phase of a generic
docket to continue its investigation of issues associated with the
unbundling of natural gas firm sales and transportation services by
local distribution companies (LDCs) in Connecticut. The first phase
of this docket was held in 1997 and deferred certain issues for future
consideration. This phase of the docket is limited to the issues of
capacity disposition (including both interstate pipeline and on-system
peaking capacity) and the cost responsibility of that capacity. Other
issues that may be reviewed are supplier of last resort, the weighted
average cost of gas and cost shifting that may have occurred as a
result of the unbundling of the industry. A final decision is due in
August 2002.
New Hampshire: Effective May 1, 2001 (competition day), utility industry
restructuring, which allows customers to choose electric suppliers, was
implemented for all customers of PSNH.
Although customers may select an electrical supplier of their own choosing,
by law PSNH is required to supply transition service for those customers
who elect not to choose an electric supplier. At present, the majority of
PSNH's customers have elected to receive transition service at a fixed
rate of $0.044 per kWh. Effective February 1, 2003, the transition service
rate will increase for all customers, excluding large commercial and
industrial customers, to $0.046 per kWh. Large commercial and industrial
customers will pay PSNH's actual and prudent cost of service for
transition service.
In July 2001, the New Hampshire Public Utilities Commission (NHPUC)
opened a docket to review the fuel and purchased-power adjustment
clause (FPPAC) cost accruals between August 2, 1999, and April 30,
2001. Hearings at the NHPUC are scheduled for June 2002. Under the
"Agreement to Settle PSNH Restructuring," the FPPAC deferrals are
recovered as a Part 3 regulatory asset through a stranded cost
recovery charge. At March 31, 2002, PSNH had approximately $179.2
million of recoverable energy costs deferred under the FPPAC, excluding
previous deferrals of purchases from independent power producers.
Management does not expect the outcome of these hearings to have a
material negative impact on its earnings.
On April 15, 2002, CL&P, NAEC and certain other joint owners reached an
agreement to sell approximately 88.2 percent of the Seabrook nuclear unit
to a subsidiary of FPL for $836.6 million, including $61.9 million for
nuclear fuel. FPL has agreed to assume responsibility for decommissioning
the unit and will receive all funds in the Seabrook decommissioning trust.
NU is obligated to top-off the decommissioning trust if its value does not
equal a previously agreed upon level. Approval of the transaction is
required from various federal and state regulatory agencies, including the
DPUC, the NHPUC, the Nuclear Regulatory Commission (NRC), the New Hampshire
Nuclear Decommissioning Financing Committee, and the Federal Energy
Regulatory Commission. NU expects to close on the sale of its 40.04
percent share of Seabrook around the end of 2002.
On October 10, 2000, NU reached an agreement with an unaffiliated 15
percent joint owner of Seabrook under which NU and that joint owner
would share the excess proceeds if the sale of Seabrook resulted in
proceeds of more than $87.2 million related to the sale of this 15
percent interest. The agreement also limits any top-off amount
required to be funded by that joint owner for decommissioning as part
of the sale process at the amount required by NRC regulations. The
excess earnings from the sale of this 15 percent interest in Seabrook
is included in the expected consolidated after-tax gains of between
$25 million and $30 million.
Massachusetts: In December 2001, the Massachusetts Department of
Telecommunications and Energy (DTE) approved approximately a 14
percent reduction in WMECO's overall rates for standard offer service
customers, primarily reflecting a reduction in WMECO's standard offer
service supply costs in 2002 from approximately $0.073 per kWh to
approximately $0.048 per kWh. The significant reduction in supply
costs in 2002 will result in a material reduction in WMECO's operating
revenues and purchased power costs in 2002, but should not impact
WMECO's financial performance since electric supply costs are passed
through to customers.
An additional contract to serve WMECO's approximately 100 MW of default
service is expected to take effect July 1, 2002. New tariffs reflecting
the bid were approved by the DTE and would result in an average cost of
$0.0491 per kWh, a decrease from a range of $0.0669 per kWh to $0.0763 per
kWh for the period of January 1, 2002, through June 30, 2002.
For further information regarding commitments and contingencies related
to restructuring and the sale of Seabrook, see Note 2A, "Commitments and
Contingencies - Restructuring," and Note 7, "Subsequent Event," to the
consolidated financial statements.
Nuclear Plant Performance and Other Matters
Seabrook: Seabrook operated at a capacity factor of 100 percent through
the first three months of 2002. Seabrook began a scheduled one-month
refueling outage on May 4, 2002, and is expected to be sold around the
end of 2002.
Other Matters
Other Commitments and Contingencies: For further information regarding
other commitments and contingencies, see Note 2, "Commitments and
Contingencies," to the consolidated financial statements.
Forward Looking Statements: This discussion and analysis includes forward
looking statements, which are statements of future expectations and not
facts including, but not limited to, statements regarding future earnings,
refinancings, the use of proceeds from restructuring, and the recovery of
operating costs. Words such as estimates, expects, anticipates, intends,
plans, and similar expressions identify forward looking statements.
Actual results or outcomes could differ materially as a result of further
actions by state and federal regulatory bodies, competition and industry
restructuring, changes in economic conditions, changes in weather patterns,
changes in laws, developments in legal or public policy doctrines,
technological developments, volatility in electric and natural gas
commodity markets, and other presently unknown or unforeseen factors.
RESULTS OF OPERATIONS
The components of significant income statement variances for the first quarter
of 2002 are provided in the table below.
Income Statement Variances
(Millions of Dollars)
2002 over/(under) 2001
----------------------
Amount Percent
------ -------
Operating Revenues $ 110 6%
Operating Expenses:
Fuel, purchased and net interchange power 222 20
Other operation (21) (10)
Maintenance (37) (41)
Depreciation (13) (21)
Amortization (649) (90)
Taxes other than income taxes (1) (2)
Gain on sale of utility plant 654 100
----- ----
Total operating expenses 155 9
----- ----
Operating income (45) (28)
----- ----
Other (loss)/income, net (171) (a)
Interest expense, net - -
----- ----
Income before income tax expense (216) (87)
Income tax expense (99) (88)
Preferred dividends of subsidiaries (1) (49)
----- ----
Income before cumulative effect of
accounting change (116) (86)
Cumulative effect of accounting
change, net of tax benefit 22 100
----- ----
Net income $ (94) (83)%
===== ====
(a) Percent greater than 100.
Operating Revenues
Total revenues increased by $110 million or 6 percent in the first quarter
of 2002, compared with the same period in 2001, primarily due to higher
revenues from the competitive energy companies ($422 million which reflects
eliminations of sales to other NU affiliates), partially offset by lower
wholesale revenues for the regulated subsidiaries ($160 million), and lower
regulated retail revenues ($140 million).
The competitive energy companies' revenue increase is primarily due to higher
revenues from Select Energy primarily as a result of increased trading volumes
resulting in physical delivery of energy trading products and the acquisition
of SENY. The wholesale revenue decrease is due to lower PSNH wholesale sales
and lower wholesale prices ($63 million), the 2001 revenue associated with
Millstone ($42 million) and lower sales associated with other purchased power
contracts ($55 million). The regulated retail revenue decrease is due to rate
decreases for PSNH and WMECO ($43 million), lower purchased gas adjustment
revenue for Yankee ($43 million) and lower retail sales ($64 million),
partially offset by an increase for CL&P resulting from the collection of
deferred fuel costs ($11 million). Regulated retail electric kWh sales
decreased by 4.0 percent and firm natural gas volume sales decreased by 17.5
percent in 2002.
Fuel, Purchased and Net Interchange Power
Fuel, purchased and net interchange power expense increased in 2002, primarily
due to higher purchased energy and capacity costs as a result of higher sales
for Select Energy ($452 million which reflects eliminations of purchases from
other NU affiliates), partially offset by lower purchased power costs for the
regulated subsidiaries ($227 million).
Other Operation and Maintenance
Other operation and maintenance (O&M) expenses decreased $58 million in 2002,
primarily due to lower nuclear expenses as a result of the sale of the
Millstone units at the end of the first quarter in 2001 ($69 million),
partially offset by higher transmission and distribution costs ($13 million).
Depreciation
Depreciation decreased in 2002 primarily due to the sale of the Millstone
units ($6 million) and PSNH restructuring ($5 million) which began on May 1,
2001.
Amortization
Amortization decreased in 2002, primarily due to higher amortization in 2001
related to the sale of the Millstone units ($684 million), partially offset
by higher amortization related to restructuring ($37 million).
Gain on Sale of Utility Plant
In 2001, NU recorded gains on the sale of CL&P's and WMECO's ownership
interests in the Millstone units. A corresponding amount of amortization
expense was recorded.
Other (Loss)/Income, Net
Other (loss)/income, net decreased primarily due to NU's 2001 recognition
of a gain in connection with the sale of Millstone units to DNCI ($202 million)
and a 2002 charge reflecting a write-down in NU's investment in NEON ($15
million), partially offset by a 2001 noncash charge related to the forward
purchase of 10.1 million NU common shares ($43 million).
Income Tax Expense
Income tax expense decreased in 2002, primarily due to the tax impacts of
the Millstone sale in 2001.
Cumulative Effect of Accounting Change, Net of Tax Benefit
The cumulative effect of accounting change, net of tax benefit, recorded
in 2001, represents the effect of the adoption of SFAS No. 133, as amended
($22 million).
INDEPENDENT ACCOUNTANTS' REPORT
To the Board of Trustees
Northeast Utilities
Berlin, Connecticut
We have reviewed the accompanying condensed consolidated balance sheet of
Northeast Utilities and subsidiaries ("the Company") as of March 31, 2002,
and the related condensed consolidated statements of income and cash flows
for the three-month period then ended. These financial statements are the
responsibility of the Company's management.
We conducted our review in accordance with standards established by the
American Institute of Certified Public Accountants. A review of interim
financial information consists principally of applying analytical procedures
to financial data and of making inquiries of persons responsible for financial
and accounting matters. It is substantially less in scope than an audit
conducted in accordance with generally accepted auditing standards, the
objective of which is the expression of an opinion regarding the financial
statements taken as a whole. Accordingly, we do not express such an opinion.
Based on our review, we are not aware of any material modifications that
should be made to such condensed consolidated financial statements for them
to be in conformity with accounting principles generally accepted in the
United States of America.
/s/ Deloitte & Touche LLP
Deloitte & Touche LLP
Hartford, Connecticut
May 10, 2002
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To Northeast Utilities:
We have reviewed the accompanying consolidated statements of income and cash
flows for the three-month period ended March 31, 2001. These financial
statements are the responsibility of the Company's management.
We conducted our review in accordance with standards established by the
American Institute of Certified Public Accountants. A review of interim
financial information consists principally of applying analytical procedures
to financial data and making inquiries of persons responsible for financial
and accounting matters. It is substantially less in scope than an audit
conducted in accordance with auditing standards generally accepted in the
United States, the objective of which is the expression of an opinion regarding
the financial statements taken as a whole. Accordingly, we do not express
such an opinion.
Based on our review, we are not aware of any material modifications that should
be made to the financial statements referred to above for them to be in
conformity with accounting principles generally accepted in the United States.
We have previously audited, in accordance with auditing standards generally
accepted in the United States, the consolidated balance sheet and consolidated
statement of capitalization as of December 31, 2001 and the related
consolidated statements of income, comprehensive income, shareholders' equity,
cash flows, and income taxes for the year then ended (not presented separately
herein), and in our report dated January 22, 2002, we expressed an unqualified
opinion on those financial statements. In our opinion, the information set
forth in the accompanying consolidated balance sheet as of December 31 2001 is
fairly stated in all material respects, in relation to the consolidated balance
sheet from which it has been derived.
/s/ Arthur Andersen LLP
Arthur Andersen LLP
Hartford, Connecticut
May 13, 2002
THE CONNECTICUT LIGHT AND POWER COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
---------------- ----------------
(Thousands of Dollars)
ASSETS
- ------
Current Assets:
Cash and cash equivalents............................ $ 2,246 $ 773
Investments in securitizable assets.................. 40,334 36,367
Notes receivable from affiliated companies........... 41,350 77,200
Receivables, net..................................... 251,734 247,801
Accounts receivable from affiliated companies........ 17,610 22,134
Unbilled revenues.................................... 4,736 7,492
Fuel, materials and supplies, at average cost........ 34,362 33,085
Prepayments and other................................ 22,122 17,703
---------------- ---------------
414,494 442,555
---------------- ---------------
Property, Plant and Equipment:
Electric utility..................................... 3,165,738 3,127,548
Less: Accumulated provision for depreciation...... 1,250,971 1,236,638
---------------- ---------------
1,914,767 1,890,910
Construction work in progress........................ 137,162 134,964
Nuclear fuel, net.................................... 2,986 3,299
---------------- ---------------
2,054,915 2,029,173
---------------- ---------------
Deferred Debits and Other Assets:
Regulatory assets.................................... 1,812,911 1,877,191
Prepaid pension...................................... 246,917 233,692
Nuclear decommissioning trusts, at market............ 6,333 6,231
Other ............................................... 176,825 138,715
---------------- ---------------
2,242,986 2,255,829
---------------- ---------------
Total Assets........................................... $ 4,712,395 $ 4,727,557
================ ===============
</Table>
The accompanying notes are an integral part of these financial statements.
THE CONNECTICUT LIGHT AND POWER COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
---------------- ----------------
(Thousands of Dollars)
LIABILITIES AND CAPITALIZATION
- ------------------------------
Current Liabilities:
Accounts payable..................................... $ 122,621 $ 132,593
Accounts payable to affiliated companies............. 78,297 85,057
Accrued taxes........................................ 36,719 34,823
Accrued interest..................................... 29,903 10,369
Other................................................ 48,743 47,342
---------------- ----------------
316,283 310,184
---------------- ----------------
Rate Reduction Bonds................................... 1,358,652 1,358,653
---------------- ----------------
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes.................... 800,523 820,444
Accumulated deferred investment tax credits.......... 94,749 95,996
Deferred contractual obligations..................... 134,844 141,497
Other................................................ 283,696 283,399
---------------- ----------------
1,313,812 1,341,336
---------------- ----------------
Capitalization:
Long-Term Debt....................................... 825,293 824,349
---------------- ----------------
Preferred Stock...................................... 116,200 116,200
---------------- ----------------
Common Stockholder's Equity:
Common stock, $10 par value - authorized
24,500,000 shares; 7,584,884 shares outstanding
in 2002 and 2001.................................. 75,849 75,849
Capital surplus, paid in........................... 413,993 414,018
Retained earnings.................................. 292,177 286,901
Accumulated other comprehensive income............. 136 67
---------------- ----------------
Common Stockholder's Equity.......................... 782,155 776,835
---------------- ----------------
Total Capitalization................................... 1,723,648 1,717,384
---------------- ----------------
Commitments and Contingencies (Note 2)
Total Liabilities and Capitalization................... $ 4,712,395 $ 4,727,557
================ ================
</Table>
The accompanying notes are an integral part of these financial statements.
THE CONNECTICUT LIGHT AND POWER COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
<Table>
<Caption>
Three Months Ended
March 31,
-------------------------------
2002 2001
-------------- --------------
(Thousands of Dollars)
Operating Revenues.................................... $ 604,420 $ 733,905
-------------- --------------
Operating Expenses:
Operation -
Fuel, purchased and net interchange power......... 358,700 426,802
Other............................................. 70,212 98,544
Maintenance.......................................... 14,524 46,844
Depreciation......................................... 23,296 28,904
Amortization of regulatory assets, net............... 25,039 558,243
Taxes other than income taxes........................ 48,538 40,196
Gain on sale of utility plant........................ - (530,724)
-------------- --------------
Total operating expenses........................... 540,309 668,809
-------------- --------------
Operating Income....................................... 64,111 65,096
Other Income, Net...................................... 3,479 25,975
-------------- --------------
Income Before Interest and Income Tax Expense.......... 67,590 91,071
-------------- --------------
Interest Expense:
Interest on long-term debt........................... 11,196 21,330
Interest on rate reduction bonds..................... 19,411 -
Other interest....................................... (198) 1,243
-------------- --------------
Interest expense, net.............................. 30,409 22,573
-------------- --------------
Income Before Income Tax Expense....................... 37,181 68,498
Income Tax Expense..................................... 15,497 30,198
-------------- --------------
Net Income............................................. $ 21,684 $ 38,300
============== ==============
</Table>
The accompanying notes are an integral part of these financial statements.
THE CONNECTICUT LIGHT AND POWER COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
<Table>
<Caption>
Three Months Ended,
March 31,
----------------------------------
2002 2001
---------------- -------------
(Thousands of Dollars)
Operating Activities:
Net income..................................................... $ 21,684 $ 38,300
Adjustments to reconcile to net cash flows
provided by operating activities:
Depreciation................................................. 23,296 28,904
Deferred income taxes and investment tax credits, net........ (11,196) (180,536)
Net amortization of recoverable energy costs................. 7,558 2,982
Amortization of regulatory assets, net....................... 25,039 558,243
Gain on sale of utility plant................................ - (530,724)
Net other sources/(uses) of cash............................. 15,788 (58,906)
Changes in working capital:
Receivables and unbilled revenues, net....................... 3,347 (155,976)
Fuel, materials and supplies................................. (1,278) (724)
Accounts payable............................................. (16,731) 493,419
Accrued taxes................................................ 1,896 204,302
Investments in securitizable assets.......................... (3,967) 11,715
Other working capital (excludes cash)........................ 16,501 15,695
-------------- -------------
Net cash flows provided by operating activities.................. 81,937 426,694
-------------- -------------
Investing Activities:
Investments in plant:
Electric utility plant....................................... (45,910) (56,821)
Nuclear fuel................................................. (25) (630)
-------------- -------------
Cash flows used for investments in plant....................... (45,935) (57,451)
Investment in NU system Money Pool............................. 35,850 (181,200)
Investments in nuclear decommissioning trusts.................. (102) (77,666)
Net proceeds from the sale of utility plant.................... - 832,353
Buyout/buydown of IPP contracts................................ - (977,433)
Other investment activities, net............................... (53,740) (255)
-------------- -------------
Net cash flows used in investing activities...................... (63,927) (461,652)
-------------- -------------
Financing Activities:
Net increase in short-term debt................................ - 50,000
Issuance of rate reduction bonds............................... - 1,438,400
Retirement of rate reduction bonds............................. (1) -
Reacquisitions and retirements of long-term debt............... - (132,250)
Cash dividends on preferred stock.............................. (1,390) (1,390)
Cash dividends on common stock................................. (15,017) (15,018)
Other financing activities, net................................ (129) 2,680
-------------- -------------
Net cash flows (used in)/provided by financing activities........ (16,537) 1,342,422
-------------- -------------
Net increase in cash and cash equivalents........................ 1,473 1,307,464
Cash and cash equivalents - beginning of period.................. 773 5,461
-------------- -------------
Cash and cash equivalents - end of period........................ $ 2,246 $ 1,312,925
============== =============
</Table>
The accompanying notes are an integral part of these financial statements.
THE CONNECTICUT LIGHT AND POWER COMPANY AND SUBSIDIARIES
Management's Discussion and Analysis of
Financial Condition and Results of Operations
CL&P is a wholly owned subsidiary of NU. This discussion should be read in
conjunction with NU's management's discussion and analysis of financial
condition and results of operations, consolidated financial statements and
footnotes in this Form 10-Q, the NU 2001 Form 10-K, and current report on
Form 8-K dated March 15, 2002.
RESULTS OF OPERATIONS
The components of significant income statement variances for the first quarter
of 2002 are provided in the table below.
Income Statement Variances
(Millions of Dollars)
2002 over/(under) 2001
----------------------
Amount Percent
------ -------
Operating Revenues $(129) (18)%
Operating Expenses:
Fuel, purchased and net interchange power (68) (16)
Other operation (28) (29)
Maintenance (32) (69)
Depreciation (6) (19)
Amortization of regulatory assets, net (533) (96)
Taxes other than income taxes 8 21
Gain on sale of utility plant 531 100
----- ----
Total operating expenses (128) (19)
----- ----
Operating income (1) (2)
----- ----
Other income, net (22) (87)
Interest expense, net 8 35
----- ----
Income before income tax expense (31) (46)
Income tax expense (14) (49)
----- ----
Net income $ (17) (43)%
===== ====
Operating Revenues
Operating revenues decreased by $129 million or 18 percent in the first
quarter of 2002 compared with the same period of 2001, primarily due to
lower wholesale revenues ($109 million), lower retail revenues ($10 million).
Wholesale revenues were lower primarily as a result of the sale of the
Millstone units at the end of the first quarter of 2001 and lower energy
sales. Retail revenues decreased primarily due to lower retail sales ($21
million) related to the mild weather in 2002, offset by the recovery of
previously deferred fuel costs through CL&P's Energy Adjustment Clause ($11
million). Retail sales decreased 3.5 percent compared to 2001.
Fuel, Purchased and Net Interchange Power
Fuel, purchased and net interchange power expense decreased in 2002, primarily
due to lower purchased power costs resulting from the buydown and buyout of
various cogeneration contracts and lower nuclear fuel expense.
Other Operation and Maintenance
Other O&M expenses decreased by $60 million in 2002, primarily due to lower
nuclear expenses ($56 million) as a result of the sale of the Millstone units
at the end of the first quarter of 2001 and lower distribution maintenance
expenses ($4 million).
Depreciation
Depreciation expense decreased in 2002, primarily due to the sale of the
Millstone units.
Amortization of Regulatory Assets, Net
Amortization of regulatory assets, net decreased in 2002, primarily due to
the amortization in 2001 related to the gain on the sale of the Millstone
units.
Taxes Other Than Income Taxes
Taxes other than income taxes increased in 2002 primarily due to the DPUC's
order for CL&P to compensate the Town of Waterford for its loss of property
tax revenue resulting from electric utility restructuring ($17 million),
partially offset by decreases in local property taxes ($4 million), payroll
taxes ($3 million) and gross earnings taxes ($1 million).
Gain on Sale of Utility Plant
In 2001, CL&P recorded a gain on the sale of its ownership share in the
Millstone units. A corresponding amount of amortization expense was recorded.
Other Income, Net
Other income, net decreased in 2002, primarily due to the gain recognized in
2001 related to the sale of the Millstone units ($29 million).
Interest Expense, Net
Interest expense, net increased in 2002, primarily due to the interest paid
on rate reduction bonds, partially offset by lower interest on other long-term
debt resulting from reacquisitions and retirements of long-term debt in 2001.
Income Tax Expense
Income tax expense decreased in 2002 primarily due to the 2001 tax impacts
of the gain on the sale of the Millstone units.
LIQUIDITY
CL&P expects to close on the sale of its 4.06 percent share of Seabrook around
the end of 2002. The net gain from the sale related to CL&P's share of
Seabrook primarily will be used to offset stranded costs and any cash received
by CL&P will be used to meet its capital requirements.
CL&P's net cash flows provided by operating activities declined to $81.9
million in the first quarter of 2002, compared with $426.7 million during the
same period of 2001. In the first quarter of 2002, cash flows provided by
operating activities decreased primarily due to a $16.6 million decrease in net
income and increased payments made on accounts payable balances in the first
quarter of 2002. These decreases were partially offset by increased receipts
received on accounts receivable balances during the first quarter of 2002,
compared with the same period of 2001.
Financing activities were significantly reduced in the first quarter of 2002,
as compared to the same quarter of 2001, primarily due to the issuance of
CL&P rate reduction certificates. The level of common dividends totaled $15
million in the first quarter of 2002, compared with $15 million during the
same period of 2001. Payment of these common dividends helped to finance
NU's share repurchases and common dividend.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
---------------- -------------------
(Thousands of Dollars)
ASSETS
- ------
Current Assets:
Cash............................................... $ 2,303 $ 1,479
Receivables, net................................... 74,696 70,540
Notes receivable from affiliated companies......... 7,400 -
Accounts receivable from affiliated companies...... 11,962 13,055
Unbilled revenues.................................. 28,326 29,268
Fuel, materials and supplies, at average cost...... 40,636 42,047
Prepayments and other.............................. 2,392 10,211
---------------- ----------------
167,715 166,600
---------------- ----------------
Property, Plant and Equipment:
Electric utility................................... 1,474,795 1,447,955
Other.............................................. 6,221 6,221
---------------- ----------------
1,481,016 1,454,176
Less: Accumulated provision for depreciation.... 697,716 689,397
---------------- ----------------
783,300 764,779
Construction work in progress...................... 47,789 44,961
---------------- ----------------
831,089 809,740
---------------- ----------------
Deferred Debits and Other Assets:
Regulatory assets.................................. 1,016,032 1,046,760
Other ............................................. 77,123 71,414
---------------- ----------------
1,093,155 1,118,174
---------------- ----------------
Total Assets......................................... $ 2,091,959 $ 2,094,514
================ ================
</Table>
The accompanying notes are an integral part of these financial statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
---------------- ----------------
(Thousands of Dollars)
LIABILITIES AND CAPITALIZATION
- ------------------------------
Current Liabilities:
Notes payable to banks................................ $ 15,000 $ 60,500
Notes payable to affiliated companies................. - 23,000
Obligations under Seabrook Power Contracts
and other capital leases - current portion.......... 27,996 24,164
Accounts payable...................................... 48,938 32,285
Accounts payable to affiliated companies.............. 22,794 18,727
Accrued taxes......................................... 20,897 2,281
Accrued interest...................................... 14,236 9,428
Overcollections....................................... 14,537 12,479
Other................................................. 12,877 12,685
---------------- ----------------
177,275 195,549
---------------- ----------------
Rate Reduction Bonds.................................... 543,586 507,381
---------------- ----------------
Obligations under Seabrook Power Contracts
and Other Capital Leases.............................. 85,634 86,111
---------------- ----------------
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes..................... 412,309 423,050
Accumulated deferred investment tax credits........... 9,681 12,015
Deferred contractual obligations...................... 36,283 37,712
Accrued pension....................................... 37,276 37,326
Other................................................. 46,395 46,260
---------------- ----------------
541,944 556,363
---------------- ----------------
Capitalization:
Long-Term Debt........................................ 407,285 407,285
---------------- ----------------
Common Stockholder's Equity:
Common stock, $1 par value - authorized
100,000,000 shares; 388 shares outstanding
in 2002 and 2001................................... - -
Capital surplus, paid in............................ 164,933 165,000
Retained earnings................................... 171,398 176,419
Accumulated other comprehensive (loss)/income....... (96) 406
---------------- ----------------
Common Stockholder's Equity........................... 336,235 341,825
---------------- ----------------
Total Capitalization.................................... 743,520 749,110
---------------- ----------------
Commitments and Contingencies (Note 2)
Total Liabilities and Capitalization.................... $ 2,091,959 $ 2,094,514
================ ================
</Table>
The accompanying notes are an integral part of these financial statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
<Table>
<Caption>
Three Months Ended
March 31,
--------------------------------
2002 2001
-------------- --------------
(Thousands of Dollars)
Operating Revenues.................................. $ 242,381 $ 340,814
-------------- --------------
Operating Expenses:
Operation -
Fuel, purchased and net interchange power...... 119,339 237,680
Other.......................................... 29,992 31,119
Maintenance....................................... 12,901 15,490
Depreciation...................................... 10,069 10,514
Amortization of regulatory assets, net............ 30,087 11,467
Taxes other than income taxes..................... 9,243 11,533
-------------- --------------
Total operating expenses........................ 211,631 317,803
-------------- --------------
Operating Income.................................... 30,750 23,011
Other Income, net................................... 97 34,305
-------------- --------------
Income Before Interest and Income Tax Expense....... 30,847 57,316
-------------- --------------
Interest Expense:
Interest on long-term debt........................ 5,979 7,602
Interest on rate reduction bonds.................. 6,926 -
Other interest.................................... (174) (61)
-------------- --------------
Interest expense, net........................... 12,731 7,541
-------------- --------------
Income Before Income Tax Expense.................... 18,116 49,775
Income Tax Expense.................................. 6,387 21,413
-------------- --------------
Net Income.......................................... $ 11,729 $ 28,362
============== ==============
</Table>
The accompanying notes are an integral part of these financial statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
<Table>
<Caption>
Three Months Ended,
March 31,
-----------------------------
2002 2001
------------ ------------
(Thousands of Dollars)
Operating activities:
Net income.......................................................... $ 11,729 $ 28,362
Adjustments to reconcile to net cash flows
provided by operating activities:
Depreciation...................................................... 10,069 10,514
Deferred income taxes and investment tax credits, net............. (11,119) (1,980)
Net amortization/(deferral) of recoverable energy costs, net...... 5,548 (24,671)
Amortization of regulatory assets, net............................ 30,087 11,467
Gain on sale of utility plant..................................... - (25,012)
Net other (uses)/sources of cash.................................. (14,700) 17,812
Changes in working capital:
Receivables and unbilled revenues, net............................ (2,121) (7,361)
Fuel, materials and supplies...................................... 1,411 (2,265)
Accounts payable.................................................. 20,719 (33,715)
Accrued taxes..................................................... 18,616 12,967
Other working capital (excludes cash)............................. 14,828 23,886
----------- -----------
Net cash flows provided by operating activities....................... 85,067 10,004
----------- -----------
Investing Activities:
Investments in plant:
Electric utility plant............................................ (27,150) (23,400)
----------- -----------
Cash flows used for investments in plant............................ (27,150) (23,400)
Investment in NU system Money Pool.................................. (30,400) (43,800)
Investments in nuclear decommissioning trusts....................... - 6,846
Other investment activities, net.................................... (4,002) (26,918)
----------- -----------
Net cash flows used in investing activities........................... (61,552) (87,272)
----------- -----------
Financing Activities:
Net decrease in short-term debt..................................... (45,500) -
Issuance of rate reduction bonds.................................... 50,000 -
Retirement of rate reduction bonds.................................. (13,795) -
Cash dividends on preferred stock................................... - (643)
Cash dividends on common stock...................................... (16,750) -
Other financing activities, net..................................... 3,354 (31,804)
----------- -----------
Net cash flows used in financing activities........................... (22,691) (32,447)
----------- -----------
Net increase/(decrease) in cash....................................... 824 (109,715)
Cash - beginning of period............................................ 1,479 115,135
----------- -----------
Cash - end of period.................................................. $ 2,303 $ 5,420
=========== ===========
</Table>
The accompanying notes are an integral part of these financial statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
Management's Discussion and Analysis of
Financial Condition and Results of Operations
PSNH is a wholly owned subsidiary of NU. This discussion should be read in
conjunction with NU's management's discussion and analysis of financial
condition and results of operations, consolidated financial statements and
footnotes in this Form 10-Q, the NU 2001 Form 10-K, and current reports on
Form 8-K dated January 30, 2002, March 15, 2002, and April 23, 2002.
RESULTS OF OPERATIONS
The components of significant income statement variances for the first quarter
of 2002 are provided in the table below.
Income Statement Variances
(Millions of Dollars)
2002 over/(under) 2001
----------------------
Amount Percent
------ -------
Operating Revenues $ (98) (29)%
Operating Expenses:
Fuel, purchased and net interchange power (118) (50)
Other operation (1) (4)
Maintenance (3) (17)
Depreciation - -
Amortization of regulatory assets, net 19 (a)
Taxes other than income taxes (2) (20)
----- ----
Total operating expenses (105) (33)
----- ----
Operating income 7 34
Other income, net (34) (100)
Interest expense, net 5 69
----- ----
Income before income tax expense (32) (64)
Income tax expense (15) (70)
----- ----
Net income $ (17) (59)%
===== ====
(a) Percent greater than 100.
Operating Revenues
Total revenues decreased by $98 million or 29 percent in the first quarter
of 2002 compared with the same period of 2001, primarily due to lower
wholesale revenues ($63 million), and lower retail revenues ($36 million).
The wholesale revenue decrease is due to lower wholesale sales and lower
wholesale prices. The retail revenues decrease is due to the May 1, 2001,
rate decrease ($24 million) and lower retail sales ($12 million). Retail
kilowatt-hour sales decreased by 6 percent in 2002.
Fuel, Purchased and Net Interchange Power
Fuel, purchased and net interchange power expense decreased in 2002, primarily
due to lower Seabrook power contract costs and lower costs associated with
wholesale sales.
Other Operation and Maintenance
Other O&M expenses decreased in 2002, primarily due to lower nuclear expenses
($2 million), fossil/hydro electric expenses ($1 million), and administrative
expenses ($1 million).
Amortization of Regulatory Assets, Net
Amortization of regulatory assets, net increased in 2002, primarily due to
higher amortizations resulting from restructuring in 2001.
Other Income, Net
Other income, net decreased in 2002, primarily due to the sale of Millstone 3
in 2001.
Interest Expense, Net
Interest expense, net increased in 2002, primarily due to the issuance of rate
reduction bonds, in April 2001.
Income Tax Expense
Income tax expense decreased in 2002, primarily due to the sale of Millstone 3
in 2001.
LIQUIDITY
On January 30, 2002, PSNH Funding LLC 2, a subsidiary of PSNH, sold $50 million
of additional rate reduction bonds, at an interest rate of 4.58 percent. The
bonds, which were rated AAA by three credit rating agencies, have a scheduled
maturity date of February 1, 2008. PSNH used the proceeds to repay short-term
debt that was incurred to buyout a purchased-power contract in December 2001.
PSNH expects to close on the sale of NAEC's 35.98 percent share of Seabrook
around the end of 2002. Following the sale of NAEC's share of Seabrook, the
Seabrook Power Contracts between PSNH and NAEC will be terminated. PSNH will
use these proceeds to more quickly amortize stranded costs.
PSNH's net cash flows provided by operating activities increased to $85.1
million in the first quarter of 2002, compared with $10 million during the
same period of 2001. In the first quarter of 2002, cash flows provided by
operating activities increased primarily due to reduced payments made on
accounts payable balances, higher amortization of regulatory assets and net
amortization of recoverable energy costs in 2002 as compared to net deferrals
in 2001. These increases were partially offset by a $16.6 million decrease
in net income compared with the same period of 2001.
The level of common dividends totaled $16.8 million in the first quarter of
2002, compared with no common dividends declared during the same period of
2001. Payment of these common dividends helped to finance NU's share
repurchases and common dividend.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
---------------- ----------------
(Thousands of Dollars)
ASSETS
- ------
Current Assets:
Cash................................................ $ 755 $ 599
Receivables, net.................................... 41,170 43,761
Accounts receivable from affiliated companies....... 6,208 2,208
Unbilled revenues................................... 10,785 12,746
Fuel, materials and supplies, at average cost....... 1,493 1,457
Prepayments and other............................... 1,063 1,544
---------------- ----------------
61,474 62,315
---------------- ----------------
Property, Plant and Equipment:
Electric utility.................................... 567,871 564,857
Less: Accumulated provision for depreciation..... 188,715 186,784
---------------- ----------------
379,156 378,073
Construction work in progress....................... 18,723 18,326
---------------- ----------------
397,879 396,399
---------------- ----------------
Deferred Debits and Other Assets:
Regulatory assets................................... 307,433 320,222
Prepaid pension..................................... 57,251 54,226
Other .............................................. 19,482 19,500
---------------- ----------------
384,166 393,948
---------------- ----------------
Total Assets......................................... $ 843,519 $ 852,662
================ ================
</Table>
The accompanying notes are an integral part of these financial statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS
(Unaudited)
<Table>
<Caption>
March 31, December 31,
2002 2001
---------------- ----------------
(Thousands of Dollars)
LIABILITIES AND CAPITALIZATION
- ------------------------------
Current Liabilities:
Notes payable to banks............................. $ 35,000 $ 50,000
Notes payable to affiliated companies.............. 27,900 9,200
Accounts payable................................... 16,024 34,970
Accounts payable to affiliated companies........... 5,237 2,982
Accrued taxes...................................... 12,903 3,691
Accrued interest................................... 1,290 2,201
Other.............................................. 11,646 10,127
--------------- ---------------
110,000 113,171
--------------- ---------------
Rate Reduction Bonds................................. 149,569 152,317
--------------- ---------------
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes.................. 226,414 229,893
Accumulated deferred investment tax credits........ 3,914 3,998
Deferred contractual obligations................... 35,569 37,357
Other.............................................. 63,224 64,309
--------------- ---------------
329,121 335,557
--------------- ---------------
Capitalization:
Long-Term Debt..................................... 101,390 101,170
--------------- ---------------
Common Stockholder's Equity:
Common stock, $25 par value - authorized
1,072,471 shares; 509,696 shares outstanding
in 2002 and 2001................................ 12,742 12,742
Capital surplus, paid in......................... 82,331 82,224
Retained earnings................................ 58,311 55,422
Accumulated other comprehensive income........... 55 59
--------------- ---------------
Common Stockholder's Equity........................ 153,439 150,447
--------------- ---------------
Total Capitalization................................. 254,829 251,617
--------------- ---------------
Commitments and Contingencies (Note 2)
Total Liabilities and Capitalization.................. $ 843,519 $ 852,662
=============== ===============
</Table>
The accompanying notes are an integral part of these financial statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
<Table>
<Caption>
Three Months Ended
March 31,
------------------------------
2002 2001
-------------- --------------
(Thousands of Dollars)
Operating Revenues.................................... $ 96,005 $ 143,300
-------------- --------------
Operating Expenses:
Operation -
Fuel, purchased and net interchange power......... 50,200 90,119
Other............................................. 10,564 18,795
Maintenance.......................................... 2,918 9,872
Depreciation......................................... 3,189 4,433
Amortization of regulatory assets, net............... 10,499 126,490
Taxes other than income taxes........................ 2,940 4,863
Gain on sale of utility plant........................ - (123,148)
-------------- --------------
Total operating expenses....................... 80,310 131,424
-------------- --------------
Operating Income....................................... 15,695 11,876
Other Loss, Net........................................ (556) (1,124)
-------------- --------------
Income Before Interest and Income Tax Expense.......... 15,139 10,752
-------------- --------------
Interest Expense:
Interest on long-term debt........................... 806 2,994
Interest on rate reduction bonds..................... 2,449 -
Other interest....................................... 317 1,900
-------------- --------------
Interest expense, net............................. 3,572 4,894
-------------- --------------
Income Before Income Tax Expense....................... 11,567 5,858
Income Tax Expense..................................... 4,677 2,539
-------------- --------------
Net Income............................................ $ 6,890 $ 3,319
============== ==============
</Table>
The accompanying notes are an integral part of these financial statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
<Table>
<Caption>
Three Months Ended,
March 31,
------------------------------
2002 2001
------------ -------------
(Thousands of Dollars)
Operating Activities:
Net income.................................................... $ 6,890 $ 3,319
Adjustments to reconcile to net cash flows
provided by operating activities:
Depreciation................................................ 3,189 4,433
Deferred income taxes and investment tax credits, net....... (3,153) (50,011)
Net amortization/(deferral) of recoverable energy costs..... 722 (1,465)
Amortization of regulatory assets, net...................... 10,499 126,490
Gain on sale of utility plant............................... - (123,148)
Net other uses of cash...................................... (29,588) (29,531)
Changes in working capital:
Receivables and unbilled revenues, net........................ 6,505 (19,185)
Fuel, materials and supplies................................ (36) 83
Accounts payable............................................ (22,644) 51,845
Accrued taxes............................................... 9,212 49,006
Other working capital (excludes cash)....................... 25,697 821
----------- ------------
Net cash flows provided by operating activities................. 7,293 12,657
----------- ------------
Investing Activities:
Investments in plant:
Electric utility plant...................................... (4,702) (8,450)
Nuclear fuel................................................ - (140)
----------- ------------
Cash flows used for investments in plant...................... (4,702) (8,590)
Investment in NU system Money Pool............................ 18,700 145,800
Investments in nuclear decommissioning trusts................. - (25,817)
Other investment activities, net.............................. 620 34,608
----------- ------------
Net cash flows provided by investing activities................. 14,618 146,001
----------- ------------
Financing Activities:
Net decrease in short-term debt............................... (15,000) (20,000)
Retirement of rate reduction bonds............................ (2,748) -
Reacquisitions and retirements of long-term debt.............. - (100,000)
Reacquisitions and retirements of preferred stock............. - (36,500)
Cash dividends on preferred stock............................. - (671)
Cash dividends on common stock................................ (4,001) (2,998)
Other financing activities, net............................... (6) 625
----------- ------------
Net cash flows used in financing activities..................... (21,755) (159,544)
----------- ------------
Net increase/(decrease) in cash................................. 156 (886)
Cash - beginning of period...................................... 599 985
----------- ------------
Cash - end of period............................................ $ 755 $ 99
=========== ============
</Table>
The accompanying notes are an integral part of these financial statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
Management's Discussion and Analysis of
Financial Condition and Results of Operations
WMECO is a wholly owned subsidiary of NU. This discussion should be read in
conjunction with NU's management's discussion and analysis of financial
condition and results of operations, consolidated financial statements and
footnotes in this Form 10-Q, the NU 2001 Form 10-K, and current report on
Form 8-K dated March 15, 2002.
RESULTS OF OPERATIONS
The components of significant income statement variances for the first quarter
of 2002 are provided in the table below.
Income Statement Variances
(Millions of Dollars)
2002 over/(under) 2001
----------------------
Amount Percent
------ -------
Operating Revenues $ (47) (33)%
Operating Expenses:
Fuel, purchased and net interchange power (40) (44)
Other operation (8) (44)
Maintenance (7) (70)
Depreciation (1) (28)
Amortization of regulatory assets, net (116) (92)
Taxes other than income taxes (2) (40)
Gain on sale of utility plant 123 100
---- ---
Total operating expenses (51) (39)
---- ---
Operating income 4 32
---- ---
Other loss, net 1 51
Interest expense, net (1) (27)
---- ---
Income before income tax expense 6 97
Income tax expense 2 84
---- ---
Net income $ 4 (a)
==== ===
(a) Percent greater than 100.
Operating Revenues
Total revenues decreased by $47 million or 33 percent in the first quarter
of 2002 compared with the same period of 2001, primarily due to lower wholesale
revenues ($22 million), and lower retail revenues ($23 million). Wholesale
revenues were lower primarily as a result of the sale of the Millstone units
at the end of the first quarter of 2001 and lower energy sales. Retail
revenues were lower as a result of the rate decrease associated with a
decrease in the standard offer supply ($19 million) and lower retail sales
($4 million). Retail sales decreased 4 percent compared to 2001.
Fuel, Purchased and Net Interchange Power
Fuel, purchased and net interchange power expense decreased in 2002, primarily
due to lower purchased power costs resulting from the buydown and buyout of
various cogeneration contracts and lower nuclear fuel expense resulting from
the sale of the Millstone units in 2001.
Other Operation and Maintenance
Other O&M expenses decreased by $15 million in 2002, primarily due to lower
nuclear expenses ($7 million) as a result of the sale of the Millstone units,
lower administrative expenses ($1 million) and lower fossil/hydro expenses
($6 million).
Depreciation
Depreciation expense decreased in 2002, primarily due to the sale of the
Millstone units.
Amortization of Regulatory Assets, Net
Amortization of regulatory assets, net decreased in 2002, primarily due to
the amortization in 2001 related to the gain on the sale of the Millstone
units.
Taxes Other Than Income Taxes
Taxes other than income taxes decreased in 2002 due to lower local property
taxes resulting from the sale of Millstone.
Gain on Sale of Utility Plant
In 2001, WMECO recorded a gain on the sale of its ownership share in the
Millstone units. A corresponding amount of amortization expense was
recorded.
Other Loss, Net
Other loss, net increased in 2002 primarily due to higher environmental
expenses in 2001.
Interest Expense, Net
Interest expense, net decreased in 2001, primarily due to the retirement
of long-term debt and lower short-term debt outstanding.
Income Tax Expense
Income tax expense decreased in 2002, primarily due to the 2001 tax
impacts of the gain on the sale of Millstone.
LIQUIDITY
WMECO's net cash flows provided by operating activities declined to $7.3
million in the first quarter of 2002, compared with $12.7 million during
the same period of 2001. In the first quarter of 2002, cash flows provided
by operating activities decreased primarily due to increased payments made
on accounts payable balances in the first quarter of 2002, compared with
the same period of 2001. This decrease was partially offset by higher net
amortization of regulatory assets, increased receipts received on accounts
receivable balances during the first quarter of 2002, compared with the
same period of 2001, and a $3.6 million increase in net income during the
first quarter of 2002, compared with the same period of 2001.
The level of common dividends totaled $4 million in the first quarter of
2002, compared with $3 million during the same period of 2001. Payment
of these common dividends helped to finance NU's share repurchases and
common dividend.
Northeast Utilities and Subsidiaries
The Connecticut Light and Power Company and Subsidiaries
Public Service Company of New Hampshire and Subsidiaries
Western Massachusetts Electric Company and Subsidiary
NOTES TO FINANCIAL STATEMENTS (Unaudited)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (All Companies)
A. Presentation
The accompanying unaudited financial statements should be read in
conjunction with the management's discussion and analysis of
financial condition and results of operations in this Form 10-Q,
the Annual Reports of Northeast Utilities (NU), The Connecticut
Light and Power Company (CL&P), Public Service Company of New
Hampshire (PSNH), and Western Massachusetts Electric Company (WMECO),
which were filed as part of the NU 2001 Form 10-K, the current
reports on Form 8-K dated January 22, 2002, January 30, 2002,
March 15, 2002, and April 23, 2002, and the current report on
Form 8-K/A dated March 15, 2002. The accompanying financial
statements contain, in the opinion of management, all adjustments
necessary to present fairly NU's and each NU system company's
financial position as of March 31, 2002, and the results of
operations and statements of cash flows for the three month
periods ended March 31, 2002 and 2001. All adjustments are of
a normal, recurring nature except those described in Notes 1C
and 2. The results of operations and statements of cash flows
for the three-month periods ended March 31, 2002 and 2001, are
not indicative of the results expected for a full year.
The consolidated financial statements of NU and of its subsidiaries
include the accounts of all their respective subsidiaries.
Intercompany transactions have been eliminated in consolidation.
The preparation of financial statements in conformity with
accounting principles generally accepted in the United States
requires management to make estimates and assumptions that
affect the reported amounts of assets and liabilities and
disclosure of contingent liabilities at the date of the
financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could
differ from those estimates.
Certain reclassifications of prior period data have been made
to conform with the current period presentation.
B. Regulatory Accounting and Assets
The accounting policies of the NU system regulated operating
companies conform to accounting principles generally accepted
in the United States applicable to rate-regulated enterprises
and historically reflect the effects of the rate-making
process in accordance with Statement of Financial Accounting
Standards (SFAS) No. 71, "Accounting for the Effects of
Certain Types of Regulation."
CL&P's, PSNH's and WMECO's transmission and distribution
businesses continue to be cost-of-service rate regulated, and
management believes the application of SFAS No. 71 to that
portion of those businesses continues to be appropriate.
Management also believes it is probable that the NU system
operating companies will recover their investments in long-lived
assets, including regulatory assets. These costs will be recovered
over a period of time ranging from 7 to 26 years, subject to
certain adjustments. The majority of the stranded costs for CL&P
and WMECO will be recovered through a transition charge over a
12-year period. PSNH has three categories of stranded costs.
Part 1 costs are securitized regulatory assets that are recovered
over the life of the related rate reduction bonds. Part 2 costs
are ongoing costs consisting of nuclear decommissioning and
independent power producer costs that are recovered as incurred,
over the time period PSNH is responsible for those costs. Part 3
costs are nonsecuritized regulatory assets which must be recovered
by a recovery end date to be determined in accordance with the
"Agreement to Settle PSNH Restructuring" (Settlement Agreement),
or which will be written off as stipulated by that Settlement
Agreement. Based on current projections, PSNH expects to fully
recover all of its Part 3 costs by the recovery end date.
In March 2000, CL&P and WMECO completed the auction of certain
hydroelectric generation assets with a book value of $129 million.
Northeast Generation Company (NGC) was the winning bidder in the
auction and paid approximately $865.5 million for these assets.
Restructuring legislation in both Connecticut and Massachusetts
requires gains from the sale of generation to be used to reduce
regulatory assets and other stranded costs. Since the entities
to the transaction are all wholly owned by NU, a gain was not
recognized. NGC is depreciating the plant assets over their
estimated useful life.
In addition, all material regulatory assets are earning a
return. The components of the NU system companies' regulatory
assets are as follows:
--------------------------------------------------------------------
March 31, December 31,
(Millions of Dollars) 2002 2001
--------------------------------------------------------------------
Recoverable nuclear costs $ 222.7 $ 231.6
Securitized regulatory assets 2,004.2 2,004.1
Income taxes, net 302.1 312.8
Unrecovered contractual
obligations 75.4 78.3
Recoverable energy costs, net 313.2 334.5
Other 265.2 326.2
--------------------------------------------------------------------
Totals $3,182.8 $3,287.5
--------------------------------------------------------------------
C. New Accounting Standards
Goodwill and Other Intangible Assets: In June 2001, the Financial
Accounting Standards Board (FASB) issued SFAS No. 142, "Goodwill
and Other Intangible Assets." This statement requires that goodwill
and indefinite-lived intangible assets should no longer be amortized
effective January 1, 2002. As of March 31, 2002, NU maintains
$315.3 million of goodwill that is no longer being amortized and
$19.7 million of identifiable intangible assets which continue to
be amortized up to the maximum useful life of 15 years. These
amounts are included on the consolidated balance sheets as goodwill
and other purchased intangible assets, net. NU does not maintain
any indefinite-lived intangible assets. The goodwill was recorded by
each of NU's reporting units as defined under SFAS No. 142 as
follows: Yankee Energy System, Inc. (Yankee) $288 million; Select
Energy Services, Inc. (SESI) $20.3 million, and Northeast Generation
Services Company (NGS) $7 million. Based on the goodwill and
intangible assets maintained by the NU system companies, under SFAS
No. 142, amortization expense will be reduced by $9 million annually.
The impact to first quarter 2002 earnings is a reduction in
amortization expense of $2.3 million or an increase in earnings per
share (EPS) of $0.02. This statement also requires that goodwill
be subject to at least an annual assessment for impairment by
applying a fair value-based test also effective January 1, 2002.
Management is in the process of the first assessment of impairment
of goodwill and expects to complete this assessment by the June 30,
2002, deadline. Upon adoption of the impairment testing rules
under SFAS No. 142, there may be a cumulative effect of an accounting
change which management has not evaluated at this time.
Asset Retirement Obligations: Also in June 2001, the FASB issued
SFAS No. 143, "Accounting for Asset Retirement Obligations." This
statement addresses financial accounting and reporting for
obligations associated with the retirement of property, plant and
equipment and the associated asset retirement costs and applies to
(a) all entities and (b) legal obligations associated with the
retirement of property, plant and equipment. SFAS No. 143 is
effective for NU's 2003 calendar year. Upon adoption of SFAS No.
143, there may be an impact on NU's consolidated financial statements
which management has not estimated at this time.
D. Other (Loss)/Income, Net
The components of the NU system companies' other (loss)/income,
net items are as follows:
---------------------------------------------------------------------
For the Three Months Ended
---------------------------------------------------------------------
March 31, March 31,
(Millions of Dollars) 2002 2001
---------------------------------------------------------------------
Loss on investment in NEON $(14.6) $ -
Gain related to Millstone sale - 202.2
Loss on share
repurchase contracts - (43.4)
Minority interest in
loss of subsidiaries - (2.3)
Other, net 0.6 0.7
---------------------------------------------------------------------
Totals $(14.0) $157.2
---------------------------------------------------------------------
2. COMMITMENTS AND CONTINGENCIES
A. Restructuring and Rate Matters (CL&P, PSNH, WMECO)
Connecticut: On September 27, 2001, CL&P filed its application with
the Connecticut Department of Public Utility Control (DPUC) for
approval of the disposition of the proceeds from the sale of the
Millstone units to a subsidiary of Dominion Resources, Inc., Dominion
Nuclear Connecticut, Inc. (DNCI). This application described and
requested DPUC approval for CL&P's treatment of its share of the
proceeds from the sale. In accordance with Connecticut's electric
utility industry restructuring legislation, CL&P was required to
utilize any gains from the Millstone sale to offset stranded costs.
There are certain contingencies related to this filing regarding the
potential disallowance of what management believes were prudently
incurred costs. Management believes the recoverability of these
costs is probable. A decision from the DPUC is expected in the
second quarter of 2002.
New Hampshire: In July 2001, the New Hampshire Public Utilities
Commission (NHPUC) opened a docket to review the fuel and purchased-
power adjustment clause (FPPAC) cost accruals between August 2,
1999, and April 30, 2001. Hearings at the NHPUC are scheduled for
June 2002. Under the Settlement Agreement, the FPPAC deferrals are
recovered as a Part 3 regulatory asset through a stranded cost
recovery charge. At March 31, 2002, PSNH had approximately $179.2
million of recoverable energy costs deferred under the FPPAC,
excluding previous deferrals of purchases from independent
power producers. Management does not expect the outcome of these
hearings to have a material negative impact on its earnings.
Massachusetts: During the first quarter of 2000, WMECO filed its
first annual stranded cost reconciliation filing covering the period
March 1, 1998 through December 31, 1999. The hearing and briefing
processes related to this filing were completed during the second
quarter of 2001. A Massachusetts Department of Telecommunications
and Energy (DTE) decision is expected in the second quarter of 2002.
On March 30, 2001, WMECO also filed its second annual stranded cost
reconciliation with the DTE for calendar year 2000 with the
related review and hearing processes anticipated to be scheduled in
2002. The cumulative deferral of unrecovered stranded costs, as
filed through calendar year 2000, is approximately $4 million.
Management believes these costs are fully recoverable.
On March 29, 2002, WMECO filed its 2001 annual transition cost
reconciliation with the DTE. This filing reconciles the recovery
of stranded generation costs for calendar year 2001. Also included
in this filing are the sales proceeds from WMECO's portion of
Millstone, the impact of securitization and approximately a $13
million benefit to ratepayers from WMECO's nuclear performance-based
ratemaking process. The inclusion of these items as part of the
reconciliation filing allows WMECO to accelerate the recovery of
total stranded generation assets. Management anticipates a formal
hearing in 2002 regarding this filing after a period of data
discovery by the DTE and other intervenors.
B. Long-Term Contractual Arrangements (Select Energy)
Select Energy, Inc. (Select Energy) maintains long-term agreements
to purchase energy in the normal course of business as part of its
portfolio of resources to meet its actual or expected sales
commitments. The aggregate amount of these purchase contracts was
$4 billion at March 31, 2002. These contracts extend through 2006
as follows (millions of dollars):
--------------------------------------------------------------------
Year
--------------------------------------------------------------------
2002 $2,923.4
2003 771.6
2004 179.4
2005 109.0
2006 43.5
--------------------------------------------------------------------
Total $4,026.9
--------------------------------------------------------------------
3. MARKET RISK AND RISK MANAGEMENT INSTRUMENTS (NU, Select Energy, Yankee,
Yankee Gas)
Derivative Instruments: Effective January 1, 2001, NU adopted SFAS
No. 133, "Accounting for Derivative Instruments and Hedging Activities,"
as amended. For those contracts that do not meet the hedging
requirements, the changes in fair value of those contracts were recognized
currently in earnings. Commodity derivatives that are utilized for
trading purposes are accounted for using the mark-to-market method, under
Emerging Issues Task Force (EITF) Issue No. 98-10, "Accounting for Energy
Trading and Risk Management Activities."
On June 27, 2001, the FASB cleared SFAS No. 133 Implementation Issue No.
C15, "Scope Exceptions: Normal Purchases and Normal Sales Exception for
Option-Type Contracts and Forward Contracts in Electricity." NU has
reviewed its capacity contracts and other applicable energy contracts and
has determined that they should not be marked-to-market under the criteria
in the guidance cleared by the FASB on June 27, 2001.
On December 19, 2001, the FASB issued revised guidance regarding power
purchase and sales agreements. The revised guidance is effective on
July 1, 2002. Management is currently evaluating the impacts of the
guidance issued by the FASB on December 19, 2001, on its accounting for
capacity contracts. However, management does not expect it to have a
material effect on its consolidated financial statements.
Competitive Energy Subsidiaries: Select Energy provides both firm
requirement energy services to its customers and engages in energy
trading and marketing activities. Select Energy manages its exposure
to risk from existing contractual commitments and provides risk management
services to its customers through forward contracts, futures,
over-the-counter swap agreements, and options (commodity derivatives).
Select Energy has utilized the sensitivity analysis methodology to
disclose the quantitative information for its commodity price risks.
Sensitivity analysis provides a presentation of the potential loss of
future earnings, fair values or cash flows from market risk-sensitive
instruments over a selected time period due to one or more hypothetical
changes in commodity prices, or other similar price changes.
Commodity Price Risk - Trading Activities: As a market participant
in the Northeast United States, Select Energy conducts commodity-
trading activities in electricity and its related products, natural
gas and oil and, therefore, experiences net open positions. Select
Energy manages these open positions with strict policies which
limit its exposure to market risk and require daily reporting to
management of potential financial exposure. Under EITF Issue No. 98-10,
these instruments are adjusted to market value, and the unrealized gains
and losses are recognized in income in the current period in the
consolidated statements of income as fuel, purchased and net interchange
power and in the consolidated balance sheets as prepayments and other.
The mark-to-market positions at March 31, 2002 and December 31, 2001,
were assets of $57.5 million and $56.4 million, respectively.
Under sensitivity analysis, the fair value of the portfolio is a
function of the underlying commodity, contract prices and market
prices represented by each derivative commodity contract. For
swaps, forward contracts and options, market value reflects
management's best estimates considering over-the-counter quotations,
time value and volatility factors of the underlying commitments.
Exchange-traded futures and options are recorded at market, based on
closing exchange prices.
As of March 31, 2002, Select Energy has calculated the market price
resulting from a 10 percent unfavorable change in forward market prices.
That 10 percent change would result in approximately a $15.5 million
decline in the fair value of the Select Energy trading portfolio.
In the normal course of business, Select Energy also faces risks that
are either nonfinancial or nonquantifiable. Such risks principally
include credit risk, which is not reflected in the aforementioned
sensitivity analysis.
Commodity Price Risk - Nontrading Activities: Select Energy
utilizes derivative financial and commodity instruments (derivatives),
including futures and forward contracts, to reduce market risk
associated with fluctuations in the price of electricity and natural
gas sold under firm commitments with certain customers. Select Energy
also utilizes derivatives, including price swap agreements, call and put
option contracts, and futures and forward contracts, to manage the
market risk associated with a portion of its anticipated supply
requirements. These derivative instruments have been designated as
cash flow hedging instruments.
When conducting sensitivity analysis of the change in the fair value
of Select Energy's electricity, natural gas and oil nontrading portfolio,
which would result from a hypothetical change in the future market price
of electricity, natural gas and oil, the fair values of the contracts are
determined from models which take into account estimated future market
prices of electricity, natural gas and oil, the volatility of the market
prices in each period, as well as the time value factors of the underlying
commitments. In most instances, market prices and volatility are
determined from quoted prices on the futures exchange.
Select Energy has determined a hypothetical change in the fair value for
its nontrading electricity, natural gas and oil contracts, assuming a 10
percent unfavorable change in forward market prices. As of March 31,
2002, an unfavorable 10 percent change in market price would have
resulted in a decline in fair value of approximately $35.3 million.
The impact of a change in electricity, natural gas and oil prices on
Select Energy's nontrading contracts on March 31, 2002, is not necessarily
representative of the results that will be realized when these contracts
are physically delivered.
Select Energy also maintains natural gas service agreements with certain
customers to supply gas at fixed prices for terms extending through 2004.
Select Energy has hedged its gas supply risk under these agreements
through New York Mercantile Exchange (NYMEX) contracts. Under these
contracts, the purchase price of a specified quantity of gas is
effectively fixed over the term of the gas service agreements, which
extend through 2004. As of March 31, 2002, the NYMEX contracts had a
notional value of $60.9 million and a mark-to-market asset value of
$1.2 million.
Derivative Cash Flow Hedge Accounting: During the first quarter of
2002, $13.7 million in income, net of tax, was reclassified from
other comprehensive income upon the conclusion of derivative cash
flow hedge transactions and recognized in earnings. An additional
$0.6 million of income, net of tax, was recognized in earnings for
those derivatives that were determined to be ineffective.
Currently, the cash flow hedge transactions entered into hedge cash
flows through 2004. As a result of these new transactions and
market value changes since January 1, 2002, other comprehensive
income increased by $19.8 million, net of tax. Accumulated other
comprehensive loss at March 31, 2002, was $3.4 million, net of tax
(reduction in equity), relating to hedged transactions and it is
estimated that $1 million, net of tax, will be reclassified as a
charge to earnings within the next twelve months. Cash flows from
the hedge contracts are reported in the same category as cash flows
from the hedged activities.
Regulated Entities:
Commodity Price Risk - Nontrading Activities: Yankee Gas Services
Company (Yankee Gas) maintains a master swap agreement with one
customer to supply gas at fixed prices for a 10-year term extending
through 2005. Under this master swap agreement, the purchase price
of a specified quantity of gas is effectively fixed over the term
of the gas service agreement, which also extends through 2005. As
of March 31, 2002, the commodity swap agreement had a notional
value of $15.3 million and a mark-to-market liability of $0.2
million, which is included within the $3.4 million reported for
accumulated other comprehensive loss related to hedging activities.
Interest Rate Risk - Nontrading Activities: Yankee has entered into
an interest rate sensitive derivative. Yankee uses swap instruments
with financial institutions to exchange fixed-rate interest
obligations for a blend between fixed and variable-rate
obligations. These instruments convert fixed interest rate
obligations to variable rates. The notional amounts parallel the
underlying debt levels and are used to measure interest to be paid
or received and do not represent the exposure to credit loss. As
of March 31, 2002, Yankee had outstanding agreements with a total
notional value of $49 million and a mark-to-market liability of
$0.1 million. Changes in this mark-to-market position are included
in earnings, as adjustments to interest expense, as this derivative
was determined to be ineffective.
Other:
Interest Rate Risk - Nontrading Activities: NU manages its interest
rate risk exposure by maintaining a mix of fixed and variable rate
debt. As of March 31, 2001, approximately 68 percent of NU's long-term
debt, including the current portion, is at a fixed interest rate. The
remaining long-term debt is variable-rate and is subject to interest
rate risk. Assuming a one percent increase in NU's variable interest
rates, interest expense would have increased approximately $4.75 million,
excluding NU parent's variable-rate debt which was refinanced in April
2002 at a fixed-rate. In addition, NU parent has entered into interest
rate sensitive derivatives. NU parent used treasury lock instruments
with financial institutions to fix the treasury rate component of
the coupon rate on the notes that were issued in April 2002. In
April 2002, the agreement ended and NU parent received $5.7 million
from the financial institutions. In accordance with SFAS No. 133,
the $5.7 million gain, net of tax, will be amortized from accumulated
other comprehensive loss over the 10-year term of the notes.
Credit Risk: Credit risk relates to the risk of loss that NU would
incur as a result of non-performance by counterparties pursuant to
the terms of their contractual obligations. NU serves a wide
variety of customers and suppliers that include independent power
producers, industrial companies, gas and electric utilities, oil
and gas producers, financial institutions, and other energy
marketers. Margin accounts exist within this diverse group, and NU
realizes interest receipts and payments related to balances
outstanding in these accounts. This wide customer and supplier mix
generates a need for a variety of contractual structures, products
and terms. This multifaceted book of business requires NU to manage
the portfolio of market risk inherent in those transactions in a
manner consistent with the parameters established by NU's risk
management process. Market risks are monitored regularly by a Risk
Oversight Council operating outside of the units that create or
actively manage these risk exposures to ensure compliance with NU's
stated risk management policies.
NU tracks and re-balances the risk in its portfolio in accordance
with mark-to-market and other risk management methodologies that
utilize forward price curves in the energy markets to estimate the
size and probability of future potential exposure.
NYMEX traded futures and option contracts are guaranteed by the
NYMEX and have a modest credit risk. NU has established written
credit policies with regard to its counterparties to minimize
overall credit risk on all types of transactions. These policies
require an evaluation of potential counterparties' financial
conditions (including credit ratings), collateral requirements
under certain circumstances (including cash in advance, letters of
credit, and parent guarantees), and the use of standardized
agreements, which allow for the netting of positive and negative
exposures associated with a single counterparty. This evaluation
results in establishing credit limits prior to NU entering into
trading activities. The appropriateness of these limits is subject
to continuing review. Concentrations among these counterparties
may impact NU's overall exposure to credit risk, either positively
or negatively, in that the counterparties may be similarly affected
by changes to economic, regulatory or other conditions.
4. COMPREHENSIVE INCOME (NU, CL&P, PSNH, WMECO)
The total comprehensive income, which includes all comprehensive
income items, for the NU system is as follows:
------------------------------------------------------------------------
Three Months Ended March 31,
------------------------------------------------------------------------
(Millions of Dollars) 2002 2001
------------------------------------------------------------------------
NU Consolidated $47.7 $116.1
CL&P 20.4 36.9
PSNH 11.2 27.7
WMECO 6.9 2.6
------------------------------------------------------------------------
Accumulated other comprehensive loss mark-to-market adjustments of
NU's qualified cash flow hedging instruments are as follows:
------------------------------------------------------------------------
(Millions of Dollars, Net of Tax) March 31, 2002
------------------------------------------------------------------------
Balance at January 1, 2002 $(36.9)
------------------------------------------------------------------------
Hedged transactions recognized into earnings 13.7
Change in fair value 19.7
Cash flow transactions entered into for the period 0.1
------------------------------------------------------------------------
Net change associated with the current period
hedging transactions 33.5
------------------------------------------------------------------------
Total mark-to-market adjustments included in
accumulated other comprehensive loss $ (3.4)
------------------------------------------------------------------------
Accumulated other comprehensive loss items unrelated to NU's qualified
cash flow hedging instruments totaled $4.4 million in income and $0.1
million in losses as of January 1, 2002, and March 31, 2002,
respectively.
5. EARNINGS PER SHARE (NU)
EPS is computed based upon the weighted average number of common shares
outstanding during each period. Diluted EPS is computed on the basis
of the weighted average number of common shares outstanding plus the
potential dilutive effect if certain securities are converted into
common stock.
The following table sets forth the components of basic and diluted
EPS:
-------------------------------------------------------------------------
(Millions of Dollars, Three Months Ended March 31,
except share information) 2002 2001
-------------------------------------------------------------------------
Income before preferred
dividends of subsidiaries $20.0 $137.3
Preferred dividends
of subsidiaries 1.4 2.7
-------------------------------------------------------------------------
Income before cumulative effect
of accounting change $18.6 $134.6
Cumulative effect
of accounting change,
net of tax benefit - (22.4)
-------------------------------------------------------------------------
Net income $18.6 $112.2
-------------------------------------------------------------------------
Basic EPS common shares
outstanding (average) 129,504,005 143,912,698
Dilutive effect of employee
stock options 250,941 401,641
-------------------------------------------------------------------------
Fully diluted EPS common shares
outstanding (average) 129,754,946 144,314,339
-------------------------------------------------------------------------
Basic and fully diluted EPS:
Income before cumulative effect
of accounting change $0.14 $0.93
Cumulative effect
of accounting change,
net of tax benefit - (0.15)
-------------------------------------------------------------------------
Net income $0.14 $0.78
-------------------------------------------------------------------------
6. SEGMENT INFORMATION (NU)
The NU system is organized between regulated utilities (electric and gas)
and competitive energy subsidiaries. The regulated utilities segment
represents approximately 55 percent and 77 percent of the NU system's
total revenues for the three months ended March 31, 2002 and 2001,
respectively, and is comprised of several business units.
Regulated utilities revenues primarily are derived from residential,
commercial and industrial customers and are not dependent on any single
customer. In 2002, the competitive energy subsidiaries segment had one
customer with revenues in excess of 10 percent of its total revenues,
CL&P. The purchases by CL&P represented approximately 15 percent of total
competitive energy subsidiaries' revenues for the three months ended
March 31, 2002. In 2001, the purchases by two customers, one unaffiliated
company and CL&P, represented approximately 15 percent and 27 percent,
respectively, of total competitive energy subsidiaries' revenues
for the three months ended March 31, 2001.
The competitive energy subsidiaries segment in the following table
includes SESI, a provider of energy management, demand-side management
and related consulting services for commercial, industrial and
institutional electric companies and electric utility companies; Holyoke
Water Power Company, a company engaged in the production of electric
power; NGC, a corporation that acquires and manages generation facilities;
Northeast Generation Services Company, a corporation that maintains
and services any fossil or hydroelectric facility that is acquired or
contracted with for fossil or hydroelectric generation services, and
Select Energy, a corporation engaged in the trading, marketing,
transportation, storage, and sale of energy commodities, at wholesale,
in designated geographical areas and in the marketing of energy products
to retail customers.
Other in the following table includes the results for Mode 1
Communications, Inc., an investor in a fiber-optic communications network.
Other also includes the results of the nonenergy related subsidiaries of
Yankee. Interest expense included in Other primarily relates to the debt
of NU parent. Inter-segment eliminations of revenues and expenses are
also included in Other.
<Table>
<Caption>
- -------------------------------------------------------------------------------------
For the Three Months Ended March 31, 2002
- -------------------------------------------------------------------------------------
Regulated Utilities Competitive Eliminations
(Millions of ------------------- Energy and
Dollars) Electric Gas Subsidiaries Other Total
- -------------------------------------------------------------------------------------
Operating
revenues $ 941.1 $104.3 $1,029.4 $(164.1) $ 1,910.7
Operating
expenses (827.5) (79.3) (1,049.5) 159.9 (1,796.4)
- ------------------------------------------------------------------------------------
Operating
income/
(loss) 113.6 25.0 (20.1) (4.2) 114.3
Other income/
(loss), net 3.1 (0.5) (3.4) (13.2) (14.0)
Interest
expense, net (47.8) (3.8) (11.1) (4.2) (66.9)
Income tax
(expense)/
benefit (27.7) (8.3) 13.0 9.6 (13.4)
Preferred
dividends (1.4) - - - (1.4)
- ------------------------------------------------------------------------------------
Net income/
(loss) $ 39.8 $ 12.4 $ (21.6) $ (12.0) $ 18.6
- ------------------------------------------------------------------------------------
Total assets $8,035.2 $888.9 $1,648.8 $(423.3) $10,149.6
- ------------------------------------------------------------------------------------
</Table>
<Table>
<Caption>
- ------------------------------------------------------------------------------------
For the Three Months Ended March 31, 2001
- ------------------------------------------------------------------------------------
Regulated Utilities Competitive Eliminations
(Millions of ------------------- Energy and
Dollars) Electric Gas Subsidiaries Other Total
- -------------------------------------------------------------------------------------
Operating
revenues $ 1,218.0 $ 174.7 $ 636.7 $ (228.9) $ 1,800.5
Operating
expenses (1,097.5) (142.8) (632.6) 232.0 (1,640.9)
- -------------------------------------------------------------------------------------
Operating
income 120.5 31.9 4.1 3.1 159.6
Other income/
(loss), net 57.5 (0.1) 1.5 98.3 157.2
Interest
expense, net (41.9) (3.4) (12.4) (9.5) (67.2)
Income tax
(expense)/
benefit (59.7) (11.3) 2.6 (43.9) (112.3)
Preferred
dividends (2.7) - - - (2.7)
- -------------------------------------------------------------------------------------
Income/(loss)
before
cumulative
effect of
accounting
change 73.7 17.1 (4.2) 48.0 134.6
Cumulative
effect of
accounting
change,
net of
tax benefit - - (22.0) (0.4) (22.4)
Net income/
(loss) $ 73.7 $ 17.1 $ (26.2) $ 47.6 $ 112.2
- -------------------------------------------------------------------------------------
Total assets $11,129.2 $ 893.4 $1,353.9 $(2,130.6) $11,245.9
- -------------------------------------------------------------------------------------
</Table>
7. SUBSEQUENT EVENT (NU, CL&P, NAEC)
On April 15, 2002, CL&P, North Atlantic Energy Corporation (NAEC) and
certain other joint owners reached an agreement to sell approximately 88.2
percent of the Seabrook nuclear unit to a subsidiary of the FPL Group,
Inc. (FPL), for $836.6 million, including $61.9 million for nuclear fuel.
FPL has agreed to assume responsibility for decommissioning the unit and
will receive all funds in the Seabrook decommissioning trust. NU is
obligated to top-off the decommissioning trust if its value does not equal
a previously agreed upon level. Approval of the transaction is required
from various federal and state regulatory agencies, including the DPUC,
the NHPUC, the Nuclear Regulatory Commission (NRC), the New Hampshire
Nuclear Decommissioning Financing Committee, and the Federal Energy
Regulatory Commission. NU expects to close on the sale of its 40.04
percent share of Seabrook around the end of 2002.
Of the approximately $400 million of total cash proceeds NU expects
to receive from the Seabrook sale, a portion of these proceeds will be
used to repay all $90 million of NAEC's outstanding debt and return all
NAEC's equity, which totaled $35.9 million as of March 31, 2002, to NU
and pay between $100 million and $120 million in taxes. Following the
sale of NAEC's share of Seabrook, the Seabrook Power Contracts between
PSNH and NAEC will be terminated. PSNH will use these proceeds to more
quickly amortize stranded costs. The net gain from the sale related to
CL&P's share of Seabrook primarily will be used to offset stranded costs
and any cash received by CL&P will be used to meet its capital
requirements.
On October 10, 2000, NU reached an agreement with an unaffiliated 15
percent joint owner of Seabrook under which NU and that joint owner
would share the excess proceeds if the sale of Seabrook resulted in
proceeds of more than $87.2 million related to the sale of this 15 percent
interest. The agreement also limits any top-off amount required to be
funded by that joint owner for decommissioning as part of the sale process
at the amount required by NRC regulations.
In conjunction with the sale of Seabrook, NU expects to record
consolidated after-tax gains of between $25 million and $30 million
related to the agreement with an unaffiliated company in connection
with the sale of their 15 percent share of Seabrook and to the
elimination of certain reserves previously set aside for the abandoned
Seabrook 2 nuclear unit. Management anticipates these gains will be
recognized during 2002.
8. LONG-TERM DEBT (WMECO)
As a result of the sale of Millstone and rate reduction bonds in early
2001, WMECO has repaid all of its first mortgage bonds and discharged
the related indenture and also all second mortgage liens that had been
placed on certain assets for the behalf of $53.8 million of pollution
control notes. Consequently, all WMECO indebtedness is unsecured at
the present time.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
1. Millstone Station - Damage to Fish Population Lawsuits
On April 20, 2000, two fishermen, Aldred Madeira, Jr. and Timothy F. Madieros,
brought a lawsuit against the Northeast Nuclear Energy Company (NNECO) and
the Northeast Utilities Service Company (NUSCO) in New London Superior Court
alleging two counts: common law nuisance and tortious interference with a
business expectancy. DNCI has since been added as an additional defendant.
The lawsuit alleges that Millstone has engaged in various actions, including
entrainment of winter flounder, that has caused the two fishermen to suffer
damages. The suit initially sought temporary and permanent injunctions to
suspend Millstone operations during the winter flounder spawning season,
conversion of Millstone to a closed-cooling system, or in the alternative,
permanent shutdown as well as compensatory and punitive damages. However, the
injunctive relief claims were dismissed by the Court on March 11, 2002.
The damage claims remain pending before the Complex Litigation Docket in
Connecticut Superior Court with discovery of information between the parties
underway.
On August 23, 2001, two additional fishermen, James Engelmann and Michael
Stepski, brought a similar lawsuit to the Madeira and Madieros action against
NNECO, NUSCO and DNCI in Superior Court alleging two counts: common law
nuisance and tortious interference with a business expectancy. Like the
earlier suit, this action also sought temporary and permanent injunctions to
suspend Millstone operations during the winter flounder spawning season and
conversion of the Millstone facility to a closed-cooling system as well as
compensatory and punitive damages. These damage claims also remain pending
before the Complex Litigation Docket in Connecticut Superior Court and are
in the early stages of litigation.
On April 26, 2000, a lawsuit was filed in Hartford Superior Court naming as
defendants the Commissioner of the Connecticut Department of Environmental
Protection (DEP), NNECO and NUSCO. This lawsuit, brought by the Connecticut
Coalition Against Millstone (CCAM), the Long Island Coalition Against
Millstone, The Connecticut Green Party, Don't Waste Connecticut and the STAR
Foundation, challenged the validity of previously issued DEP emergency and
temporary authorizations allowing Millstone to discharge wastewater not
expressly authorized by the facility's water discharge National Pollutant
Discharge Elimination System (NPDES) permit. On October 16, 2000, this
matter was dismissed by the Superior Court. After the plaintiffs' motion
for reargument was denied, CCAM and the Long Island Coalition Against Millstone
filed an appeal with the Connecticut Appellate Court. The matter is now
subject to assignment for oral argument during the May/June term of the
Appellate Court. On May 3, 2002, based on the Connecticut Appellate Court's
dismissal as moot of CCAM's appeal of the DPUC decision approving the sale of
Millstone station, NUSCO and NNECO moved to dismiss this appeal as moot.
2. Sale of Millstone to DNCI
In February 2001, the CCAM filed in Connecticut Superior Court an appeal of
the DPUC's decision approving the sale of Millstone to DNCI. CCAM alleges
that the final decision violates the Connecticut general statutes on multiple
grounds and requests that the decision be reversed and vacated. In March
2001, CCAM filed a motion to stay, which was heard by the court later that
month. On March 26, 2001, CCAM's appeal was dismissed. On April 16, 2001,
the plaintiffs filed an appeal with the Connecticut Appellate Court. On
February 21, 2002, the Court dismissed CCAM's appeal and, on April 23, 2002,
the Connecticut Supreme Court denied CCAM's request for review of the Appellate
Court's dismissal of the appeal.
On March 8, 2001, CCAM filed suit against DEP, NNECO and DNCI challenging the
validity of Millstone's NPDES Permit and a previously issued DEP emergency
authorization allowing Millstone to discharge wastewater not expressly
authorized by the facility's NPDES Permit. The suit also challenged DEP's
authority to transfer both Millstone's NPDES Permit and emergency authorization
to DNCI. On July 19, 2001, this matter was dismissed by the Superior Court
and on August 27, 2001, CCAM filed an appeal with the Connecticut Appellate
Court. The matter is now subject to assignment for oral argument during the
May/June term of the Appellate Court. On May 3, 2002, based on the Connecticut
Appellate Court's dismissal as moot of CCAM's appeal of the DPUC's decision
approving the sale of Millstone station, NNECO and DNCI moved to dismiss this
appeal as moot. For further information on the sale of the Millstone units,
see Item 1, "Business - Rates and Electric Industry Restructuring" and
"Business - Nuclear Generation" in NU's 2001 Form 10-K.
3. Consolidated Edison, Inc./NU - Merger Appeals and Related Litigation
Discovery in the litigation in the United States District Court for the
Southern District of New York between Consolidated Edison, Inc. and NU
relating to the parties' October 13, 1999, Agreement and Plan of Merger,
as amended and restated as of January 11, 2000, is now complete. Motions
for summary judgment are expected to be filed by the parties on or before
May 10, 2002. No trial date has yet been set by the court.
For information relating to the Merger Agreement and the related litigation,
see "Part I, Item 3 - Legal Proceedings" in NU's 2001 Annual Report on
Form 10-K.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Listing of Exhibits
Exhibit No. Description
----------- -----------
4.1.4 Indenture dated as of April 1, 2002, between Northeast
Utilities and The Bank of New York as Trustee (Exhibit A-3
to NU 35-CERT filed April 16, 2002, File No.70-9535)
4.1.5 First Supplemental Indenture dated as of April 1, 2002
between Northeast Utilities and The Bank of New York as
Trustee (Exhibit A-4 to NU 35-CERT filed April 16, 2002,
File No. 70-9535)
10.63 Purchase and Sale Agreement for the Seabrook Nuclear
Power Station by and among NAEC, The United Illuminating
Company, Great Bay Power Corporation, New England Power
Company, CL&P, Canal Electric Company, Little Bay Power
Corporation, New Hampshire Electric Cooperative, Inc.,
North Atlantic Energy Service Corporation and FPL Energy
Seabrook, LLC, dated April 13, 2002.
15 Deloitte & Touche LLP Letter Regarding Unaudited Financial
Information
15.1 Arthur Andersen LLP Letter Regarding Unaudited Financial
Information
(b) Reports on Form 8-K:
NU filed a current report on Form 8-K dated January 22, 2002, disclosing:
o NU's earnings press release for the fourth quarter and full year 2001.
NU, PSNH and PSNH Funding LLC 2 filed current reports on Form 8-K dated
January 30, 2002, disclosing:
o The closing on the sale of $50 million of rate reduction bonds through
PSNH's subsidiary, PSNH Funding LLC 2.
NU, CL&P, PSNH, WMECO, and NGC filed current reports on Form 8-K dated
March 15, 2002, disclosing:
o NU's change in its certifying accountant.
NU filed a current report on Form 8-K/A dated March 15, 2002, disclosing:
o An amendment to NU's current report on Form 8-K dated March 15, 2002,
disclosing NU's change in its certifying accountant.
NU and PSNH filed current reports on Form 8-K dated April 23, 2002, disclosing:
o NU's earnings press release for the first quarter of 2002 and the
announcement of the proposed sale of the Seabrook nuclear unit.
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 hereunto duly authorized.
NORTHEAST UTILITIES
-------------------
Registrant
Date: May 9, 2002 By /s/ John H. Forsgren
----------- ----------------------------------------
John H. Forsgren
Vice Chairman,
Executive Vice President
and Chief Financial Officer
Date: May 9, 2002 By /s/ John P. Stack
----------- ----------------------------------------
John P. Stack
Vice President - Accounting
and Controller
- -------------------------------------------------------------------------------
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 hereunto duly authorized.
THE CONNECTICUT LIGHT AND POWER COMPANY
---------------------------------------
Registrant
Date: May 9, 2002 By /s/ Randy A. Shoop
----------- ----------------------------------------
Randy A. Shoop
Treasurer
Date: May 9, 2002 By /s/ John P. Stack
----------- ----------------------------------------
John P. Stack
Vice President - Accounting
and Controller
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 hereunto duly authorized.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
---------------------------------------
Registrant
Date: May 9, 2002 By /s/ David R. McHale
----------- ----------------------------------------
David R. McHale
Vice President and Treasurer
Date: May 9, 2002 By /s/ John P. Stack
----------- ----------------------------------------
John P. Stack
Vice President - Accounting
and Controller
- -------------------------------------------------------------------------------
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 hereunto duly authorized.
WESTERN MASSACHUSETTS ELECTRIC COMPANY
--------------------------------------
Registrant
Date: May 9, 2002 By /s/ David R. McHale
----------- ----------------------------------------
David R. McHale
Vice President and Treasurer
Date: May 9, 2002 By /s/ John P. Stack
----------- ----------------------------------------
John P. Stack
Vice President - Accounting
and Controller