EXHIBIT 13.3
2002 Annual Report
Western Massachusetts Electric Company and Subsidiary
Index
Contents Page
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Management's Discussion and Analysis of Financial
Condition and Results of Operations........................... 1
Independent Auditors' Report and Report of
Independent Public Accountants............................... 7
Consolidated Balance Sheets..................................... 8-9
Consolidated Statements of Income............................... 10
Consolidated Statements of Comprehensive Income................. 10
Consolidated Statements of Common Stockholder's Equity.......... 11
Consolidated Statements of Cash Flows........................... 12
Notes to Consolidated Financial Statements...................... 13
Selected Consolidated Financial Data............................ 22
Consolidated Quarterly Financial Data (Unaudited)............... 22
Consolidated Statistics (Unaudited)............................. 23
Bondholder Information.......................................... Back Cover
Management's Discussion and Analysis
Financial Condition
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Overview
Western Massachusetts Electric Company (WMECO or the company), a wholly owned
subsidiary of Northeast Utilities (NU), earned $37.7 million in 2002 compared
with $15 million in 2001. The improved 2002 results were largely due to the
recognition of $13 million in investment tax credits and the elimination of
$9 million of reserves, both in 2002, as a result of regulatory decisions.
NU's other subsidiaries include The Connecticut Light and Power Company
(CL&P), Public Service Company of New Hampshire (PSNH), Yankee Energy System,
Inc., North Atlantic Energy Corporation, Select Energy, Inc. (Select Energy),
Northeast Generation Company, Northeast Generation Services Company, and
Select Energy Services, Inc.
WMECO's revenues during 2002 decreased to $369.5 million from $478.9 million
during 2001 primarily due to lower retail revenues and lower wholesale and
other revenues. Retail revenues were lower primarily due to a decrease in
the standard offer service rate partially offset by higher distribution
revenues from higher retail sales. This decrease in revenues is offset by a
corresponding decrease in fuel, purchased and net interchange power expense.
Wholesale revenues were lower primarily due to the inclusion in 2001 of
revenue from the output of the Millstone nuclear units (Millstone) and the
lower sales of energy and capacity due to the buydown and buyout of various
cogenerator contracts.
Future Outlook
WMECO is expected to have reduced earnings in 2003 compared to 2002. The
primary reason for the earnings decrease at WMECO is that the positive
results from 2002 regulatory decisions are not expected in 2003. Another
reason for the earnings reduction at WMECO is a significant reduction in the
projected level of pension income in 2003 and forward.
WMECO recorded $12.1 million of pre-tax pension income in 2002, approximately
30 percent of which was capitalized and reflected as a reduction to the cost
of capital expenditures with the remainder being recognized in the
consolidated statements of income as reductions to operating expenses. In
2003, as a result of continued poor performance in the equity markets, WMECO
is projecting the total level of pre-tax pension income to decline to
approximately $7 million, with a similar percent being reflected as a
reduction to the cost of capital expenditures. Pension income is annually
adjusted during the second quarter based upon updated actuarial valuations,
and the 2003 estimate may be modified.
Liquidity
In November 2002, WMECO, along with NU's other regulated utilities, renewed
their $300 million credit line, under terms similar to the arrangement that
expired in November 2002. A previous credit line had provided up to $350
million for the regulated companies. WMECO had $7 million in borrowings on
this credit line at December 31, 2002.
Rate reduction bonds are included on the consolidated balance sheets of
WMECO, even though the debt is nonrecourse to WMECO. At December 31, 2002,
WMECO had a total of $142.7 million in rate reduction bonds outstanding,
compared with $152.3 million outstanding at December 31, 2001. All
outstanding rate reduction bonds of WMECO are scheduled to be fully amortized
by June 1, 2013. Interest on the rate reduction bonds totaled $9.6 million
in 2002, compared with $6.3 million in 2001. Amortization of the rate
reduction bonds totaled $9.6 million in 2002, compared with $2.7 million in
2001. WMECO fully recovered the amortization and interest payments from
customers in 2002 and the bonds had no impact on net income. Moreover,
because the debt is nonrecourse to WMECO, the three rating agencies that rate
WMECO's debt do not include the revenues, expenses, or outstanding securities
related to the rate reduction bonds in establishing the credit ratings of
WMECO.
WMECO has applied to the Massachusetts Department of Telecommunications and
Energy (DTE) to refinance approximately $100 million of short-term and spent
nuclear fuel obligations. A decision is expected in the first half of 2003.
WMECO's net cash flows provided by operating activities decreased to $27.9
million in 2002, compared with $57.5 million in 2001. Cash flows provided by
operating activities decreased primarily due to changes in working capital
items, primarily receivables and unbilled revenues and accounts payable,
partially offset by the increase in net income in 2002.
There was a lower level of investing and financing activities in 2002 as
compared to 2001, primarily due to the retirement of long-term debt, issuance
of rate reduction bonds and buyout of independent power producer contracts in
2001. The level of common dividends totaled $16 million in 2002, as compared
to $22 million in 2001.
Business Development and Capital Expenditures
As a result of a lower than projected growth rate and an adequately sized
transmission system to meet near term needs, WMECO does not forecast
significant changes in its construction program. WMECO's capital
expenditures, excluding nuclear fuel, totaled $23.4 million in 2002, compared
with $30.9 million in 2001. WMECO's capital expenditures are expected to
total $28.1 million in 2003.
Regional Transmission Organization
The Federal Energy Regulatory Commission (FERC) has required all transmission
owning utilities, including WMECO, to voluntarily start forming regional
transmission organizations (RTO) or to state why this process has not begun.
WMECO has been discussing with the other transmission owners in New England
the potential to form an Independent Transmission Company (ITC). If formed,
the ITC would be a for-profit entity and would perform certain transmission
functions required by the FERC including tariff control, system planning and
system operations. The remaining functions required by the FERC would be
performed by the Independent System Operator (ISO) regarding the energy
market and short-term reliability. Together, the ITC, if formed, and ISO
would form the FERC-desired RTO.
In January 2002, the New York and New England ISOs announced their intention
to form an RTO. On November 22, 2002, the two ISOs withdrew their joint
petition to FERC. The New England ISO intends to make an RTO filing with the
transmission owners in New England in 2003. The agreements needed to create
the RTO and to define the working relationships among the ISO and the
transmission owners should be created in 2003, and will allow the RTO to
begin operation shortly thereafter. The agreements are expected to include
provisions for the future creation of one or more ITCs within the RTO. The
creation of the RTO will require a FERC rate case, and the impact on WMECO's
return on equity as a result of this rate case cannot be estimated at this
time. At December 31, 2002, WMECO capitalized $0.2 million related to RTO
formation activities.
Restructuring and Rate Matters
In December 2001, the DTE approved approximately a 14 percent reduction in
WMECO's overall rates for standard offer service, primarily reflecting a
reduction in WMECO's standard offer service supply costs in 2002 to
approximately $0.048 per kilowatt-hour (kWh) from approximately $0.073 per
kWh. In December 2002, the DTE approved an overall increase of approximately
1.8 percent in WMECO's non-contract standard offer rates, primarily
reflecting slightly increased standard offer and default service costs as
well as other inflationary factors. Select Energy, an NU affiliate, won the
bid to supply WMECO with standard offer service in 2003 at an average rate of
approximately $0.050 per kWh. An unaffiliated company won a bid to serve
WMECO with default service for the period of January 1, 2003 through June 30,
2003, at an average price of $0.051 per kWh.
On June 7, 2002, the DTE issued its decision on WMECO's 1998 through 1999
stranded cost reconciliation. The decision included, among other things, a
conclusion that investment tax credits associated with generation assets that
have been divested should not be returned to ratepayers. As a result, WMECO
recognized approximately $13 million in tax credits during the second quarter
of 2002.
On March 30, 2001, WMECO filed its second annual stranded cost reconciliation
with the DTE for calendar year 2000. On March 29, 2002, WMECO filed its 2001
annual transition cost reconciliation with the DTE. This filing reconciled
the recovery of stranded generation costs for calendar year 2001 and includes
sales proceeds from WMECO's portion of the Millstone units, the impact of
securitization and approximately a $13 million benefit to ratepayers from
WMECO's nuclear performance-based ratemaking process.
Subsequently, WMECO and the office of the Massachusetts Attorney General
reached a settlement resolving all transition charge issues for the 1998
through 2001 reconciliations. This settlement was filed for DTE review on
December 3, 2002 and approved on December 27, 2002. The settlement had a
positive impact of $9 million on WMECO 2002 pre-tax earnings.
For further information regarding commitments and contingencies related to
restructuring, see Note 5A, "Commitments and Contingencies - Restructuring
and Rate Matters," to the consolidated financial statements.
Nuclear Generation Asset Divestitures
VYNPC: On July 31, 2002, Vermont Yankee Nuclear Power Corporation (VYNPC)
consummated the sale of its nuclear generating unit. WMECO owns 2.6 percent
of VYNPC.
Millstone: On March 31, 2001, WMECO and CL&P consummated the sale of
Millstone 1 and 2, and WMECO, CL&P and PSNH sold their ownership interests in
Millstone 3.
Under the terms of these asset divestitures, the purchasers agreed to assume
responsibility for decommissioning their respective units. For further
information regarding nuclear decommissioning, see Note 4, "Nuclear
Generation Asset Divestitures," Note 5F, "Commitments and Contingencies -
Nuclear Decommissioning and Plant Closure Costs" to the consolidated
financial statements. For further information regarding spent nuclear fuel
disposal costs, see Note 5C, "Commitments and Contingencies - Spent Nuclear
Fuel Disposal Costs," to the consolidated financial statements.
Critical Accounting Policies and Estimates
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States of America requires
management to make estimates, assumptions and at times difficult, subjective
or complex judgments. Changes in these estimates, assumptions and judgments,
in and of themselves, could materially impact the financial condition of
WMECO. The following describes accounting policies and estimates that
management believes are the most critical in nature:
Presentation: In accordance with current accounting pronouncements, WMECO's
consolidated financial statements include all subsidiaries upon which
significant control is maintained and all intercompany transactions between
these subsidiaries are eliminated as part of the consolidation process.
WMECO has less than 50 percent ownership interests in the Connecticut Yankee
Atomic Power Company, Yankee Atomic Electric Company, Maine Yankee Atomic
Power Company, and VYNPC, which are classified as variable interest entities
under Financial Accounting Standards Board Interpretation No. 46,
"Consolidation of Variable Interest Entities," and for which WMECO was not
classified as the primary beneficiary. As a result, management does not
expect the adoption of Interpretation No. 46 to result in the consolidation
of any currently unconsolidated entities or to have any other material
impacts on WMECO's consolidated financial statements.
Revenue Recognition: WMECO revenues are based on rates approved by the DTE.
These regulated rates are applied to customers' accounts based on their use
of energy. In general, rates can only be changed through formal proceedings
with the DTE.
The determination of the energy sales to individual customers is based on the
reading of their meters, which occurs on a systematic basis throughout the
month. At the end of each month, amounts of energy delivered to customers
since the date of the last meter reading are estimated and the corresponding
unbilled revenue is estimated. This unbilled revenue is estimated each month
based on generation volumes, estimated customer usage by class, line losses,
and applicable customer rates.
Regulatory Accounting and Assets: The accounting policies of WMECO
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." WMECO's transmission and
distribution businesses continue to be cost-of-service rate regulated, and
management believes the application of SFAS No. 71 continues to be
appropriate. Management must reaffirm this conclusion at each balance sheet
date. If, as a result of a change in circumstances, it is determined that
any portion of the transmission and distribution businesses no longer meets
the criteria of regulatory accounting under SFAS No. 71, that portion of the
business would have to discontinue regulatory accounting and write-off
regulatory assets. Such a write-off could have a material impact on WMECO's
consolidated financial statements.
The application of SFAS No. 71 results in the deferral of costs as regulatory
assets that, in some cases, have not yet been approved for recovery by the
applicable regulatory commission. Management must conclude that any costs
deferred as regulatory assets are probable of future recovery in rates.
However, the regulatory commission can reach different conclusions about the
recovery of costs, which can have a material impact on WMECO's consolidated
financial statements. Management believes that it is probable that WMECO
will recover its investments in long-lived assets, including regulatory
assets.
Pension and Postretirement Benefit Obligations: WMECO participates in a
uniform noncontributory defined benefit retirement plan (Plan) covering
substantially all regular NU employees and also provides certain health care
benefits, primarily medical and dental, and life insurance benefits through a
benefit plan to retired employees. For each of these plans, the development
of the benefit obligation, fair value of plan assets, funded status, and net
periodic benefit credit or cost is based on several significant assumptions.
If these assumptions were changed, the resultant change in benefit
obligations, fair values of plan assets, funded status, and net periodic
benefit credits or costs could have a material impact on WMECO's consolidated
financial statements.
WMECO's pre-tax periodic pension income for the Plan, excluding settlements,
curtailments, and special termination benefits, totaled $12.1 million and
$13.7 million for the years ended December 31, 2002 and 2001, respectively.
Pension income is calculated based upon a number of actuarial assumptions,
including an expected long-term rate of return on Plan assets of 9.25 percent
for 2002 and 9.5 percent for 2001. WMECO expects to use a long-term rate of
return assumption of 8.75 percent for 2003. The pension income amounts
exclude one-time items recorded under SFAS No. 88, "Employers' Accounting for
Settlements and Curtailments of Defined Benefit Pension Plans and for
Termination Benefits," associated with early termination programs and the
sale of the Millstone nuclear units. Net SFAS No. 88 items totaled $1.2
million of income and $0.3 million in expense for the years ended
December 31, 2002 and 2001, respectively. Approximately 30 percent of net
pension income is capitalized as a reduction to capital additions to utility
plant.
In developing the expected long-term rate of return assumption, WMECO
evaluated input from actuaries, consultants and economists as well as long-
term inflation assumptions and NU's historical 20-year compounded return of
10.7 percent. NU's expected long-term rate of return on Plan assets is
based on target asset allocation assumptions of 45 percent in United States
equities and 14 percent in non-United States equities, both with expected
long-term rates of return of 9.25 percent, 3 percent in emerging market
equities with an expected long-term return of 10.25 percent, 20 percent in
fixed income securities with an expected long-term rate of return of 5.5
percent, 5 percent in high yield fixed income securities with expected long-
term rates of return of 7.5 percent, 8 percent in private equities with
expected long-term rates of return of 14.25 percent, and 5 percent in real
estate with expected long-term rates of return of 7.5 percent. The
combination of these target allocations and expected returns results in the
overall assumed long-term rate of return of 8.75 percent for 2003. The
actual asset allocation at December 31, 2002, was close to these target asset
allocations, and WMECO regularly reviews the actual asset allocations and
periodically rebalances the investments to the targeted allocation when
appropriate. WMECO reduced the long-term rate of return assumption by 0.5
percent and 0.25 percent, respectively, each of the last two years due to
lower rate of return assumptions for most asset classes. WMECO believes that
8.75 percent is a reasonable long-term rate of return on Plan assets for
2003. WMECO will continue to evaluate the actuarial assumptions, including
the expected rate of return, at least annually, and will adjust the
appropriate assumptions as necessary.
WMECO bases the actuarial determination of Plan pension income/expense on a
market-related valuation of assets, which reduces year-to-year volatility.
This market-related valuation recognizes investment gains or losses over a
four-year period from the year in which they occur. Investment gains or
losses for this purpose are the difference between the expected return
calculated using the market-related value of assets and the actual return
based on the fair value of assets. Since the market-related value of assets
recognizes gains or losses over a four-year period, the future value of the
market-related assets will be impacted as previously deferred gains or losses
are recognized. There will be no impact on the fair value of Plan assets.
At December 31, 2002, WMECO's portion of the Plan had cumulative unrecognized
investment losses of $50.5 million, which will increase Plan expense over the
next four years by reducing the expected return on Plan assets. At
December 31, 2002, WMECO's portion of the Plan also had cumulative
unrecognized actuarial gains of $17.7 million, which will reduce Plan expenses
over the expected future working lifetime of active Plan participants, or
approximately 13 years. The combined total of unrecognized investment losses
and actuarial gains at December 31, 2002 is $32.8 million. This amount
impacts the actuarially determined prepaid pension amount recorded on the
consolidated balance sheet but has no impact on expected Plan funding.
The discount rate that is utilized in determining future pension obligations
is based on a basket of long-term bonds that receive one of the two highest
ratings given by a recognized rating agency. To compensate for the Plan's
longer duration 0.25 percent was added to this rating. The discount rate
determined on this basis has decreased from 7.25 percent at December 31, 2001
to 6.75 percent at December 31, 2002.
Due to the effect of the unrecognized actuarial losses and based on an
expected rate of return on Plan assets of 8.75 percent, a discount rate of
6.75 percent and various other assumptions, WMECO estimates that pension
income/expense for the Plan will be approximately $7 million in income,
approximately $3 million in income and approximately $0.1 million in expense
in 2003, 2004 and 2005, respectively. Future actual pension income/expense
will depend on future investment performance, changes in future discount
rates and various other factors related to the populations participating in
the plan.
The value of WMECO's portion of the Plan assets has decreased from $191.2
million at December 31, 2001 to $162.4 million at December 31, 2002. The
investment performance returns and declining discount rates have reduced the
funded status of WMECO's portion of the Plan, on a projected benefit
obligation (PBO) basis, from an overfunded position of $69.9 million at
December 31, 2001 to $28.8 million at December 31, 2002. The PBO includes
expectations of future employee service and compensation increases. The
significant deterioration in the funded position of the Plan will likely
result in Plan contributions sooner than previously expected. WMECO has not
made contributions since 1991. This deterioration could also lead to the
requirement under defined benefit plan accounting to record an additional
minimum liability. The total accumulated benefit obligation (ABO) of the
entire Plan was $78 million less than Plan assets at December 31, 2002. The
ABO is the obligation for employee service provided through December 31,
2002. If the ABO exceeds Plan assets, WMECO may need to record an additional
minimum liability in 2003.
Income Taxes: Income tax expense is calculated for each period for which a
statement of income is presented. This process involves estimating WMECO's
actual current tax exposures as well as assessing temporary differences
resulting from differing treatment of items, such as timing of the deduction
of expenses for tax and book accounting purposes. These differences result
in deferred tax assets and liabilities, which are included in the
consolidated balance sheets. WMECO must also assess the likelihood that the
deferred tax assets will be recovered from future taxable income, and to the
extent that recovery is not likely, a valuation allowance must be
established. Significant management judgment is required in determining
income tax expense, deferred tax assets and liabilities and valuation
allowances. WMECO accounts for deferred taxes under SFAS No. 109 "Accounting
for Income Taxes." For temporary differences recorded as deferred tax
liabilities that will be recovered in rates in the future, WMECO has
established a regulatory asset. This asset amounted to $54.2 million and
$57.3 million at December 31, 2002 and 2001, respectively.
Depreciation: Depreciation expense is calculated based on an asset's useful
life, and judgment is involved when estimating the useful lives of certain
assets. A change in the estimated useful lives of these assets could have a
material impact on WMECO's consolidated financial statements.
Environmental Matters: At December 31, 2002, WMECO has recorded a reserve
for various environmental liabilities. WMECO's environmental liabilities are
based on the best estimate of the amounts to be incurred for the
investigation, remediation and monitoring of the remediation sites. It is
possible that future cost estimates will either increase or decrease as
additional information becomes known.
Special Purpose Entity: WMECO has one special purpose entity, which is
currently consolidated in the financial statements. During 2001, to
facilitate the issuance of rate reduction certificates intended to finance
certain stranded costs, WMECO established WMECO Funding LLC. The funding
company was created as part of state sponsored securitization programs.
WMECO Funding LLC is restricted from engaging in non-related activities and
is required to operate in a manner intended to reduce the likelihood that it
would be included in WMECO's bankruptcy estate if they ever become involved
in such bankruptcy proceedings.
For further information regarding these types of activities, see Note 1,
"Summary of Significant Accounting Policies," Note 3, "Pension Benefits and
Postretirement Benefits Other Than Pensions," Note 5B, "Commitments and
Contingencies - Environmental Matters," and Note 10, "Income Tax Expense," to
the consolidated financial statements.
Other Matters
Other Commitments and Contingencies: For further information regarding other
commitments and contingencies, see Note 5, "Commitments and Contingencies,"
to the consolidated financial statements.
Contractual Obligations and Commercial Commitments: Information regarding
WMECO's contractual obligations and commercial commitments as of December 31,
2002, is summarized through 2007 as follows:
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(Millions of
Dollars) 2003 2004 2005 2006 2007
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Notes payable
to banks $ 7.0 $ - $ - $ - $ -
Operating leases 3.5 3.4 3.2 2.9 2.3
Long-term contractual
arrangements 10.6 10.3 9.9 9.8 9.6
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Totals $21.1 $13.7 $13.1 $12.7 $11.9
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Rate reduction bond amounts are not included in this table. For further
information regarding WMECO's contractual obligations and commercial
commitments, see Note 2, "Short-Term Debt," and Note 5E, "Commitments and
Contingencies - Long-Term Contractual Arrangements," 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,
and other presently unknown or unforeseen factors.
Results of Operations
The components of significant income statement variances for the past two
years are provided in the table below.
<Table>
<Caption>
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2002 over/(under)2001 2001 over/(under) 2000
Income Statement Variances --------------------- -----------------------
(Millions of Dollars) Amount Percent Amount Percent
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Operating Revenues $(109) (23)% $ (35) (7)%
Operating Expenses:
Fuel, purchased and net interchange power (135) (43) 70 28
Other operation (18) (26) (9) (12)
Maintenance (5) (26) (13) (41)
Depreciation 1 4 (4) (22)
Amortization of regulatory assets, net (92) (70) 84 (a)
Taxes other than income taxes (2) (18) (6) (26)
Gain on sale of utility plant 120 (a) (120) (a)
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Total operating expenses (131) (30) 2 1
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Operating income 22 58 (37) (50)
Interest expense, net (1) (6) (10) (40)
Other income/(loss), net - - (2) (a)
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Income before income tax expense 23 (a) (29) (57)
Income tax expense - - (9) (57)
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Net income/(loss) $ 23 (a)% $ (20) (58)%
============================================================================================
</Table>
(a) Percent greater than 100.
Operating Revenues
Operating revenues decreased $109 million or 23 percent in 2002, primarily
due to lower retail revenues ($71 million) and lower wholesale and other
revenue ($38 million). Retail revenues were lower primarily due to a
decrease in the standard offer service rate resulting from a competitive bid
process required by the DTE ($109 million) partially offset by an increase in
the transition charge rate ($32 million) and higher distribution revenues
from higher retail sales ($11 million). Retail sales increased by 1.9
percent. The decrease in revenues related to the standard offer service rate
is offset by a corresponding decrease in fuel, purchased and net interchange
power expense. Wholesale revenues were lower primarily due to the inclusion
in 2001 of revenue from the output of the Millstone nuclear units ($14
million) and the lower sales of energy and capacity due to the buydown and
buyout of various cogenerator contracts ($12 million). The buydown and
buyout of cogeneration contracts has a corresponding decrease in fuel,
purchased and net interchange power expense.
Operating revenues decreased $35 million or 7 percent in 2001, primarily due
to lower wholesale revenues ($85 million), partially offset by higher
regulated retail revenues ($52 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 sales of energy and capacity. Retail
revenues increased primarily due to an increase in the standard offer service
rate partially offset by lower retail sales. Retail sales decreased by 0.9
percent compared to 2000.
Fuel, Purchased and Net Interchange Power
Fuel, purchased and net interchange power expense decreased $135 million in
2002, primarily due to the lower supply price for standard offer service
($109 million), the buydown and buyout of various cogeneration contracts ($12
million) and lower nuclear fuel expense ($9 million).
Fuel, purchased and net interchange power expense increased in 2001,
primarily due to higher purchased energy costs associated with the standard
offer supply.
Other Operation and Maintenance
Other operation and maintenance (O&M) expenses decreased $23 million in 2002,
primarily due to the lack of nuclear expenses in 2002 as a result of the sale
of Millstone units at the end of the first quarter in 2001 ($12 million) and
lower administrative and general expenses ($9 million).
Other O&M expenses decreased in 2001, primarily due to lower nuclear expenses
($29 million) as a result of the sale of the Millstone units at the end of
the first quarter in 2001 and lower transmission and distribution expenses
($2 million), partially offset by higher administrative and general expenses
($10 million).
Depreciation
Depreciation increased $1 million in 2002, primarily due to an increase in
utility plant balances.
Depreciation expense decreased in 2001, primarily due to the elimination of
decommissioning expenses as a result of the sale of the Millstone units at
the end of the first quarter of 2001.
Amortization of Regulatory Assets, Net
Amortization of regulatory assets, net decreased $92 million in 2002
primarily due to the amortization in 2001 related to the sale of the
Millstone units ($120 million) and lower amortization related to the recovery
of the Millstone investment ($9 million), partially offset by higher
amortizations in 2002 related to the recovery of stranded costs ($37
million).
Amortization of regulatory assets, net increased in 2001, primarily due to
the amortization in 2001 related to the gain from the sale of Millstone ($120
million), partially offset by lower amortization of nuclear-related
transition costs ($22 million) and the current deferral of transition costs
($23 million).
Taxes Other Than Income Taxes
Taxes other than income taxes decreased $2 million in 2002 and $6 million in
2001, primarily due to decreases in local property taxes.
Gain on Sale of Utility Plant
WMECO recorded a $120 million gain in 2001 on the sale of its ownership
interest in Millstone. A corresponding amount of amortization expense was
recorded.
Interest Expense, Net
Interest expense, net decreased $1 million in 2002 and $10 million in 2001,
primarily due to retirement of long-term debt in 2001.
Other Income/(Loss), Net
Other income/(loss), net was unchanged due to lower environmental costs
recorded in 2002 ($3 million) offset by the DTE's order in 2002 resulting in
an adjustment to the gain from the sale of the fossil units ($3 million).
Other income/(loss), net decreased in 2001, primarily due to higher
environmental reserves in 2001, partially offset by the settlement, in 2000,
of Millstone-related litigation, net of insurance proceeds ($2 million).
Income Tax Expense
Income tax expense remained unchanged in 2002 as a result of higher book
income offset by the recognition in 2002 of investment tax credits as a
result of a regulatory decision ($13 million).
Income tax expense decreased in 2001, primarily due to lower revenues
resulting from the sale of Millstone.
Independent Auditors' Report
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To the Board of Directors
of Western Massachusetts Electric Company:
We have audited the accompanying consolidated balance sheet of Western
Massachusetts Electric Company and subsidiary (a Massachusetts corporation
and a wholly owned subsidiary of Northeast Utilities) (the "Company") as of
December 31, 2002, and the related consolidated statements of income,
comprehensive income, common stockholder's equity, and cash flows for the
year then ended. The consolidated financial statements of the Company as of
December 31, 2001 and 2000, and for the years then ended, were audited by
other auditors who have ceased operations. Those auditors expressed an
unqualified opinion on those financial statements in their report dated
January 22, 2002. These financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
financial statements based on our audit.
We conducted our audit in accordance with auditing standards generally
accepted in the United States of America. Those standards require that we
plan and perform the audit to obtain reasonable assurance about whether the
financial statements are free of material misstatement. An audit includes
examining, on a test basis, evidence supporting the amounts and disclosures
in the financial statements. An audit also includes assessing the accounting
principles used and significant estimates made by management, as well as
evaluating the overall financial statement presentation. We believe that our
audit provides a reasonable basis for our opinion.
In our opinion, the 2002 consolidated financial statements present fairly, in
all material respects, the financial position of Western Massachusetts
Electric Company and subsidiary as of December 31, 2002, and the results of
their operations and their cash flows for the year then ended in conformity
with accounting principles generally accepted in the United States of
America.
/s/ DELOITTE & TOUCHE LLP
---------------------
DELOITTE & TOUCHE LLP
Hartford, Connecticut
January 28, 2003
Report of Independent Public Accountants
- ----------------------------------------
To the Board of Directors
of Western Massachusetts Electric Company:
We have audited the accompanying consolidated balance sheets of Western
Massachusetts Electric Company (a Massachusetts corporation and a wholly
owned subsidiary of Northeast Utilities) and subsidiary as of December 31,
2001 and 2000, and the related consolidated statements of income,
comprehensive income, common stockholder's equity and cash flows for each
of the three years in the period ended December 31, 2001. These financial
statements are the responsibility of the company's management. Our
responsibility is to express an opinion on these financial statements based
on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the
financial statements are free of material misstatement. An audit includes
examining, on a test basis, evidence supporting the amounts and disclosures
in the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by management, as
well as evaluating the overall financial statement presentation. We
believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Western Massachusetts
Electric Company and subsidiary as of December 31, 2001 and 2000, and the
results of their operations and their cash flows for each of the three
years in the period ended December 31, 2001, in conformity with accounting
principles generally accepted in the United States.
/s/ ARTHUR ANDERSEN LLP
-------------------
ARTHUR ANDERSEN LLP
Hartford, Connecticut
January 22, 2002
Readers of these consolidated financial statements should be aware that
this report is a copy of a previously issued Arthur Andersen LLP report
and that this report has not been reissued by Arthur Andersen LLP.
Furthermore, this report has not been updated since January 22, 2002,
and Arthur Andersen LLP completed its last post-audit review of
December 31, 2001, consolidated financial information on May 13, 2002.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS
<Table>
<Caption>
- -----------------------------------------------------------------------------------------------
At December 31, 2002 2001
- -----------------------------------------------------------------------------------------------
(Thousands of Dollars)
ASSETS
- ------
Current Assets:
Cash........................................................ $ 123 $ 599
Receivables, less provision for uncollectible
accounts of $1,958 in 2002 and $2,028 in 2001............. 42,203 43,761
Accounts receivable from affiliated companies............... 6,369 2,208
Unbilled revenues........................................... 8,944 12,746
Fuel, materials and supplies, at average cost............... 1,821 1,457
Prepayments and other....................................... 1,470 1,544
-------- --------
60,930 62,315
-------- --------
Property, Plant and Equipment:
Electric utility............................................ 590,153 564,857
Less: Accumulated depreciation........................... 195,804 186,784
-------- --------
394,349 378,073
Construction work in progress............................... 11,860 18,326
-------- --------
406,209 396,399
-------- --------
Deferred Debits and Other Assets:
Regulatory assets........................................... 283,702 320,222
Prepaid pension............................................. 67,516 54,226
Other ...................................................... 18,304 19,500
-------- --------
369,522 393,948
-------- --------
Total Assets.................................................. $836,661 $852,662
======== ========
</Table>
The accompanying notes are an integral part of these consolidated financial
statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS
<Table>
<Caption>
- -----------------------------------------------------------------------------------------
At December 31, 2002 2001
- -----------------------------------------------------------------------------------------
(Thousands of Dollars)
LIABILITIES AND CAPITALIZATION
- ------------------------------
Current Liabilities:
Notes payable to banks................................... $ 7,000 $ 50,000
Notes payable to affiliated companies.................... 85,900 9,200
Accounts payable......................................... 17,730 34,970
Accounts payable to affiliated companies................. 6,233 2,982
Accrued taxes............................................ 4,334 3,691
Accrued interest......................................... 2,059 2,201
Other.................................................... 8,005 10,127
-------- --------
131,261 113,171
-------- --------
Rate Reduction Bonds....................................... 142,742 152,317
-------- --------
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes........................ 222,065 229,893
Accumulated deferred investment tax credits.............. 3,662 3,998
Deferred contractual obligations......................... 63,767 37,357
Other.................................................... 13,213 64,309
-------- --------
302,707 335,557
-------- --------
Capitalization:
Long-Term Debt........................................... 101,991 101,170
-------- --------
Common Stockholder's Equity:
Common stock, $25 par value - authorized
1,072,471 shares; 434,653 shares outstanding
in 2002 and 509,696 shares outstanding in 2001........ 10,866 12,742
Capital surplus, paid in............................... 69,712 82,224
Retained earnings...................................... 77,476 55,422
Accumulated other comprehensive (loss)/income.......... (94) 59
-------- --------
Common Stockholder's Equity.............................. 157,960 150,447
-------- --------
Total Capitalization....................................... 259,951 251,617
-------- --------
Commitments and Contingencies (Note 5)
Total Liabilities and Capitalization....................... $836,661 $852,662
======== ========
</Table>
The accompanying notes are an integral part of these consolidated financial
statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF INCOME
<Table>
<Caption>
- ---------------------------------------------------------------------------------------------------
For the Years Ended December 31, 2002 2001 2000
- ---------------------------------------------------------------------------------------------------
(Thousands of Dollars)
Operating Revenues...................................... $369,487 $478,869 $513,678
-------- -------- --------
Operating Expenses:
Operation -
Fuel, purchased and net interchange power.......... 181,485 315,903 246,130
Other.............................................. 49,039 66,458 75,940
Maintenance........................................... 14,499 19,635 33,111
Depreciation.......................................... 14,381 13,818 17,693
Amortization of regulatory assets, net................ 39,712 131,876 47,775
Taxes other than income taxes......................... 10,688 13,065 17,759
Gain on sale of utility plant......................... - (119,775) -
-------- -------- --------
Total operating expenses........................ 309,804 440,980 438,408
-------- -------- --------
Operating Income........................................ 59,683 37,889 75,270
Interest Expense:
Interest on long-term debt............................ 2,942 4,940 13,754
Interest on rate reduction bonds...................... 9,587 6,251 -
Other interest........................................ 1,857 4,120 11,788
-------- -------- --------
Interest expense, net.............................. 14,386 15,311 25,542
-------- -------- --------
Other (Loss)/Income, Net................................ (850) (1,050) 685
-------- -------- --------
Income Before Income Tax Expense........................ 44,447 21,528 50,413
Income Tax Expense...................................... 6,765 6,560 15,145
-------- -------- --------
Net Income.............................................. $ 37,682 $ 14,968 $ 35,268
======== ======== ========
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net Income.............................................. $ 37,682 $ 14,968 $ 35,268
-------- -------- --------
Other comprehensive (loss)/income, net of tax:
Unrealized (losses)/gains on securities............... (110) (123) 22
Minimum pension liability adjustments................. (43) - -
-------- -------- --------
Comprehensive Income.................................... $ 37,529 $ 14,845 $ 35,290
======== ======== ========
</Table>
The accompanying notes are an integral part of these consolidated financial
statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
<Table>
<Caption>
- ----------------------------------------------------------------------------------------------------------------------
Accumulated
Capital Other
Common Surplus, Retained Comprehensive Total
Stock Paid In Earnings Income/(Loss) (a)
- ----------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
Balance at January 1, 2000........................ $ 26,812 $171,691 $ 38,712 $ 160 $237,375
Net income for 2000........................... 35,268 35,268
Cash dividends on preferred stock............. (2,798) (2,798)
Cash dividends on common stock................ (12,002) (12,002)
Repurchase of common stock.................... (12,060) (77,940) (90,000)
Capital stock expenses, net................... 259 259
Allocation of benefits - ESOP (b)............. 3,772 3,772
Other comprehensive income.................... 22 22
-------- -------- -------- ----- --------
Balance at December 31, 2000...................... 14,752 94,010 62,952 182 171,896
Net income for 2001........................... 14,968 14,968
Cash dividends on preferred stock............. (404) (404)
Cash dividends on common stock................ (22,000) (22,000)
Repurchase of common stock.................... (2,010) (12,990) (15,000)
Capital stock expenses, net................... 1,204 1,204
Allocation of benefits - ESOP................. (94) (94)
Other comprehensive loss...................... (123) (123)
-------- -------- -------- ----- --------
Balance at December 31, 2001...................... 12,742 82,224 55,422 59 150,447
Net income for 2002........................... 37,682 37,682
Cash dividends on common stock................ (16,009) (16,009)
Repurchase of common stock.................... (1,876) (12,123) (13,999)
Capital stock expenses, net................... 131 131
Allocation of benefits - ESOP................. (520) 381 (139)
Other comprehensive loss...................... (153) (153)
-------- -------- -------- ----- --------
Balance at December 31, 2002...................... $ 10,866 $ 69,712 $ 77,476 $ (94) $157,960
======== ======== ======== ===== ========
</Table>
(a) The company has no dividend restrictions. However, the company has two
tests it must meet before it can pay out any dividends. The most
restrictive of which limits the company to paying out no greater than
$77.5 million of equity at December 31, 2002.
(b) In June 1999, WMECO paid NU parent $6.9 million for NU shares issued from
1992 through 1998 on behalf of its employees in accordance with NU's 401(k)
plan. This transaction resulted in a reduction of the NU parent loss and
a tax benefit to WMECO. The amount in 2000 represents the remaining
previously unallocated 1993 through 1999 NU parent losses.
The accompanying notes are an integral part of these consolidated financial
statements.
WESTERN MASSACHUSETTS ELECTRIC COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF CASH FLOWS
<Table>
<Caption>
- ------------------------------------------------------------------------------------------------------------------
For the Years Ended December 31, 2002 2001 2000
- ------------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
Operating Activities:
Net income...................................................... $ 37,682 $ 14,968 $ 35,268
Adjustments to reconcile to net cash flows
provided by operating activities:
Depreciation.................................................. 14,381 13,818 17,693
Deferred income taxes and investment tax credits, net......... (26,952) 5,281 (11,549)
Net (deferral)/amortization of recoverable energy costs....... (529) 3,179 9,386
Amortization of regulatory assets, net........................ 39,712 131,876 47,775
Gain on sale of utility plant................................. - (119,775) -
Prepaid pension............................................... (13,290) (8,453) (45,773)
Net other (uses)/sources of cash.............................. (8,221) (988) 26,570
Changes in working capital:
Receivables and unbilled revenues, net........................ 1,199 15,017 (24,637)
Fuel, materials and supplies.................................. (365) 149 1,491
Accounts payable.............................................. (13,989) 4,043 17,727
Accrued taxes................................................. 643 (4,780) 7,882
Other working capital (excludes cash)......................... (2,351) 3,204 (7,321)
-------- --------- --------
Net cash flows provided by operating activities................... 27,920 57,539 74,512
-------- --------- --------
Investing Activities:
Investments in plant:
Electric utility plant........................................ (23,428) (30,921) (27,267)
Nuclear fuel.................................................. - (140) (7,848)
-------- --------- --------
Cash flows used for investments in plant........................ (23,428) (31,061) (35,115)
NU system Money Pool borrowing/(lending)........................ 76,700 8,600 (8,800)
Investments in nuclear decommissioning trusts................... - (23,037) (3,437)
Net proceeds from the sale of utility plant..................... - 175,154 185,787
Buyout of IPP contract.......................................... - (80,000) -
Other investment activities, net................................ 937 817 3,589
-------- --------- --------
Net cash flows provided by investing activities................... 54,209 50,473 142,024
-------- --------- --------
Financing Activities:
Repurchase of common stock...................................... (13,999) (15,000) (90,000)
Issuance of rate reduction bonds................................ - 155,000 -
Retirement of rate reduction bonds.............................. (9,575) (2,683) -
Net decrease in short-term debt................................. (43,000) (60,000) (13,000)
Reacquisitions and retirements of long-term debt................ - (100,000) (94,150)
Reacquisitions and retirements of preferred stock............... - (36,500) (1,500)
Retirement of capital lease obligation.......................... - (34,200) -
Cash dividends on preferred stock............................... - (404) (2,798)
Cash dividends on common stock.................................. (16,009) (22,000) (12,002)
Other financing activities, net................................. (22) 7,389 (3,051)
-------- --------- --------
Net cash flows used in financing activities....................... (82,605) (108,398) (216,501)
-------- --------- --------
Net (decrease)/increase in cash................................... (476) (386) 35
Cash - beginning of year.......................................... 599 985 950
-------- --------- ---------
Cash - end of year................................................ $ 123 $ 599 $ 985
========= ========= =========
Supplemental Cash Flow Information:
Cash paid during the year for:
Interest, net of amounts capitalized............................ $ 14,934 $ 17,939 $ 26,055
======== ========= ========
Income taxes.................................................... $ 32,522 $ 6,314 $ 18,554
======== ========= ========
</Table>
The accompanying notes are an integral part of these consolidated financial
statements.
Notes to Consolidated Financial Statements
1. Summary of Significant Accounting Policies
A. About Western Massachusetts Electric Company
Western Massachusetts Electric Company (WMECO or the company) along with The
Connecticut Light and Power Company (CL&P), and Public Service Company of New
Hampshire (PSNH), North Atlantic Energy Corporation (NAEC), Holyoke Water
Power Company (HWP) and Yankee Energy System, Inc. (Yankee) are the operating
companies comprising the Northeast Utilities system and are wholly owned by
Northeast Utilities (NU). WMECO furnishes franchised retail electric service
in western Massachusetts, while CL&P and PSNH furnish franchised retail
electric service in Connecticut and New Hampshire. NAEC previously sold all
of its entitlement to the capacity and output of the Seabrook Station nuclear
unit (Seabrook) to PSNH under the terms of two life-of-unit, full cost
recovery contracts (Seabrook Power Contracts). Seabrook was sold on
November 1, 2002. NU's other subsidiaries include HWP, a company engaged in
the production of electric power, Yankee, the parent company of Yankee Gas
Services Company (Yankee Gas), Connecticut's largest natural gas distribution
system, and several other competitive subsidiaries including Select Energy,
Inc., Northeast Generation Company, Northeast Generation Services Company,
and Select Energy Services, Inc.
WMECO is registered with the Securities and Exchange Commission (SEC) under
the Securities Exchange Act of 1934. NU is registered with the SEC as a
holding company under the Public Utility Holding Company Act of 1935 (1935
Act) and NU, including WMECO, is subject to the provisions of the 1935 Act.
Arrangements among WMECO, other NU companies, outside agencies, and other
utilities covering interconnections, interchange of electric power and sales
of utility property are subject to regulation by the Federal Energy
Regulatory Commission (FERC) and/or the SEC. WMECO is subject to further
regulation for rates, accounting and other matters by the FERC and the
Massachusetts Department of Telecommunications and Energy (DTE).
Several wholly owned subsidiaries of NU provide support services for NU's
companies, including WMECO, and in some cases, for other New England
utilities. Northeast Utilities Service Company (NUSCO) provides centralized
accounting, administrative, engineering, financial, information resources,
legal, operational, planning, purchasing, and other services to NU's
companies. Until the sale of Seabrook on November 1, 2002, North Atlantic
Energy Service Corporation had operational responsibility for Seabrook.
Three other subsidiaries construct, acquire or lease some of the property and
facilities used by NU's companies.
B. Presentation
The consolidated financial statements of WMECO include the accounts of its
subsidiary WMECO Funding LLC. Intercompany transactions have been eliminated
in consolidation.
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States of America 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 years' data have been made to conform with
the current year's presentation.
C. New Accounting Standards
Asset Retirement Obligations: In June 2001, the Financial Accounting
Standards Board (FASB) issued Statement of Financial Accounting Standards
(SFAS) No. 143, "Accounting for Asset Retirement Obligations." This
statement requires that legal obligations associated with the retirement of
property, plant and equipment be recognized as a liability at fair value when
incurred and when a reasonable estimate of the fair value of the liability
can be made. SFAS No. 143 is effective on January 1, 2003, for WMECO.
Management has completed its review process for potential asset retirement
obligations (AROs) and has not identified any material AROs which have been
incurred. However, management has identified certain removal obligations
which arise in the ordinary course of business that either have a low
probability of occurring or are not material in nature. These types of
obligations primarily relate to transmission and distribution lines and
poles, telecommunication towers, transmission cables and certain FERC or
state regulatory agency re-licensing issues.
A portion of WMECO's rates is intended to recover the cost of removal of
certain utility assets. The amounts recovered do not represent AROs. At
December 31, 2002, WMECO maintained approximately $16.6 million in total cost
of removal regulatory liabilities, which are included in the accumulated
provision for depreciation.
Guarantees: In November 2002, the FASB issued Interpretation No. 45,
"Guarantor's Accounting and Disclosure Requirements for Guarantees, Including
Indirect Guarantees of Indebtedness of Others." Interpretation No. 45
requires that disclosures be made by a guarantor in its interim and annual
financial statements about its obligations under certain guarantees that it
has issued and clarifies that a guarantor is required to recognize, at the
inception of a guarantee, a liability for the fair value of the obligation
undertaken in issuing the guarantee. Interpretation No. 45 does not apply to
certain guarantee contracts, such as residual value guarantees provided by
lessees in capital leases, guarantees that are accounted for as derivatives,
guarantees that represent contingent consideration in a business combination,
guarantees issued between either parents and their subsidiaries or
corporations under common control, a parent's guarantee of a subsidiary's
debt to a third party, and a subsidiary's guarantee of the debt owed to a
third party by either its parent or another subsidiary of that parent. The
initial recognition and initial measurement provisions of Interpretation No.
45 are applicable to WMECO on a prospective basis to guarantees issued or
modified after January 1, 2003. Currently, management does not expect the
adoption of the initial recognition and initial measurement provisions of
Interpretation No. 45 to have a material impact on WMECO's consolidated
financial statements.
Consolidation of Variable Interest Entities: In January 2003, the FASB
issued Interpretation No. 46, "Consolidation of Variable Interest Entities."
Interpretation No. 46 addresses the consolidation and disclosure requirements
for companies that hold an equity interest in a variable interest entity
(VIE), regardless of the date on which the VIE was created. Interpretation
No. 46 requires consolidation of a VIE's assets, liabilities and
noncontrolling interests at fair value when a company is the primary
beneficiary, which is defined as a company that absorbs a majority of the
expected losses, risks and revenues from the VIE as a result of holding a
contractual or other financial interest in the VIE. Consolidation is not
required under Interpretation No. 46 for those companies that hold a
significant equity interest in a VIE but are not the primary beneficiary.
Interpretation No. 46 is effective for WMECO beginning in the third quarter
of 2003. At December 31, 2002, WMECO held equity interests in various VIEs,
for which WMECO was not the primary beneficiary, as WMECO does not absorb a
majority of the expected losses, risks and revenues from the VIEs or provide
a substantial portion of financial support. As a result, management does not
expect the adoption of Interpretation No. 46 to have a material impact on
WMECO's consolidated financial statements. For further information regarding
WMECO's investments in its VIEs, see Note 1D, "Equity Investments and Jointly
Owned Electric Utility Plant" to the consolidated financial statements.
D. Equity Investments and Jointly Owned Electric Utility Plant
Regional Nuclear Generating Companies: WMECO owns common stock in four
regional nuclear companies (Yankee Companies). WMECO's ownership interests in
the Yankee Companies at December 31, 2002 and 2001, which are accounted for
on the equity method are 9.5 percent of the Connecticut Yankee Atomic Power
Company (CYAPC), 7 percent of the Yankee Atomic Electric Company (YAEC), 3
percent of the Maine Yankee Atomic Power Company (MYAPC), and 2.6 percent of
the Vermont Yankee Nuclear Power Corporation (VYNPC). WMECO's total equity
investment in the Yankee Companies and its exposure to loss as a result of
these investments at December 31, 2002 and 2001, is $8.6 million and $9.3
million, respectively. These investments are VIEs under FASB Interpretation
No. 46. Excluding VYNPC, which sold its nuclear generating plant, each
Yankee Company owns a single decommissioned nuclear generating plant. On
July 31, 2002, VYNPC consummated the sale of its nuclear generating plant to
a subsidiary of Entergy Corporation for approximately $180 million.
E. Depreciation
The provision for depreciation is calculated using the straight-line method
based on estimated remaining useful lives of depreciable utility plant-in-
service, which range primarily from 15 years to 60 years, adjusted for
salvage value and removal costs, as approved by the appropriate regulatory
agency where applicable. Depreciation rates are applied to the average plant-
in-service from the time they are placed in service. When plant is retired
from service, the original cost of the plant, including costs of removal less
salvage, is charged to the accumulated provision for depreciation. The
depreciation rates for the several classes of electric plant-in-service are
equivalent to a composite rate of 2.3 percent in 2002 and 2001 and 2.2
percent in 2000.
F. Revenues
Revenues are based on rates approved by the DTE. These regulated rates are
applied to customer's accounts based on their use of energy. In general,
rates can only be changed through formal proceedings with the DTE.
The determination of the energy sales to individual customers is based on the
reading of their meters, which occurs on a systematic basis throughout the
month. At the end of each month, amounts of energy delivered to customers
since the date of the last meter reading are estimated and the corresponding
unbilled revenue is estimated. This unbilled revenue is estimated each month
based on generation volumes, estimated customer usage by class, line losses,
and applicable customer rates.
G. Regulatory Accounting and Assets
The accounting policies of WMECO conform to accounting principles generally
accepted in the United States of America applicable to rate-regulated
enterprises and historically reflect the effects of the rate-making process
in accordance with SFAS No. 71, "Accounting for the Effects of Certain Types
of Regulation."
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 WMECO will recover its
investments in long-lived assets, including regulatory assets. In addition,
all material regulatory assets are earning a return, except for securitized
regulatory assets. The components of WMECO's regulatory assets are as
follows:
- --------------------------------------------------------------------------
At December 31,
- --------------------------------------------------------------------------
(Millions of Dollars) 2002 2001
- --------------------------------------------------------------------------
Recoverable nuclear costs $ 38.0 $ 38.5
Securitized regulatory assets 141.9 149.6
Income taxes, net 54.2 57.3
Unrecovered contractual
obligations 63.8 37.4
Recoverable energy costs, net 4.3 3.8
Other (18.5) 33.6
- --------------------------------------------------------------------------
Totals $283.7 $320.2
- --------------------------------------------------------------------------
At December 31, 2002, other regulatory assets included a regulatory
liability in the amount of $29.8 million, related to the WMECO rate cap
deferral.
In March 2001, WMECO sold its ownership interest in the Millstone units. The
gain on this sale of approximately $119.8 million was used to offset
recoverable nuclear costs, resulting in a total unamortized balance of $7.1
million and $3.2 million at December 31, 2002 and 2001, respectively. Also
included in recoverable nuclear costs for 2002 and 2001 are $30.9 million
and $35.3 million, respectively, primarily related to Millstone 1 recoverable
nuclear costs associated with the recoverable portion of the undepreciated
plant and related assets.
In May 2001, WMECO issued $155 million in rate reduction certificates and
used $80 million of those proceeds to buyout an independent power producer
contract. The majority of the payment to buyout this contract was recorded
as a securitized regulatory asset.
WMECO, under the terms of contracts with the Yankee Companies, is responsible
for its proportionate share of the remaining costs of the units, including
decommissioning. These amounts are recorded as unrecovered contractual
obligations. A portion of these obligations was securitized in 2001 and is
included in securitized regulatory assets. During 2002, WMECO was notified
by the Yankee Companies that the estimated cost of decommissioning their
units had increased over prior estimates due to higher anticipated costs for
spent fuel storage, security and liability and property insurance. In
December 2002, WMECO recorded an additional $32.4 million in deferred
contractual obligations and a corresponding increase in the unrecovered
contractual obligations regulatory asset as a result of these increased
costs.
WMECO, under the Energy Policy Act of 1992 (Energy Act), was assessed for
its proportionate share of the costs of decontaminating and decommissioning
uranium enrichment plants owned by the United States Department of Energy
(DOE) (D&D Assessment) when they owned nuclear generating plants. The
Energy Act requires that regulators treat D&D Assessments as a reasonable
and necessary current cost of fuel, to be fully recovered in rates like any
other fuel cost. WMECO is currently recovering these costs through rates.
At December 31, 2002 and 2001, WMECO's total D&D Assessment deferrals were
$4.3 million and $3.8 million, respectively, and have been recorded as
recoverable energy costs, net.
H. Income Taxes
The tax effect of temporary differences (differences between the periods in
which transactions affect income in the financial statements and the periods
in which they affect the determination of taxable income) is accounted for in
accordance with the rate-making treatment of the applicable regulatory
commissions and SFAS No. 109, "Accounting for Income Taxes."
The tax effect of temporary differences, including timing differences accrued
under previously approved accounting standards, that give rise to the
accumulated deferred tax obligation is as follows:
- --------------------------------------------------------------------------
At December 31,
- --------------------------------------------------------------------------
(Millions of Dollars) 2002 2001
- --------------------------------------------------------------------------
Accelerated depreciation and
other plant-related differences $ 66.6 $107.5
Regulatory assets:
Nuclear stranded investment and
other asset divestitures 57.3 52.3
Securitized contract termination
costs and other 34.8 38.4
Income tax gross-up 21.1 19.0
Other 42.3 12.7
- --------------------------------------------------------------------------
Totals $222.1 $229.9
- --------------------------------------------------------------------------
I. Other Income/(Loss), Net
The components of WMECO's other income/(loss), net items are as follows:
- --------------------------------------------------------------------------
For the Years Ended December 31,
- --------------------------------------------------------------------------
(Millions of Dollars) 2002 2001 2000
- --------------------------------------------------------------------------
Investment income $ 1.6 $ 0.9 $ 3.6
Other, net (2.5) (2.0) (2.9)
- --------------------------------------------------------------------------
Totals $(0.9) $(1.1) $ 0.7
- --------------------------------------------------------------------------
2. Short-Term Debt
Limits: The amount of short-term borrowings that may be incurred by WMECO is
subject to periodic approval by either the SEC under the 1935 Act or by the
DTE. Currently, SEC authorization allows WMECO to incur total short-term
borrowings up to a maximum of $250 million.
Credit Agreement: On November 12, 2002, WMECO, CL&P, PSNH, and Yankee Gas
entered into a 364-day unsecured revolving credit facility for $300 million.
This facility replaced a $350 million facility for WMECO, CL&P, PSNH and
Yankee Gas, which expired on November 15, 2002. WMECO may draw up to $100
million under this facility. Unless extended, the credit facility will
expire on November 11, 2003. At December 31, 2002 and 2001, there were $7
million and $50 million in borrowings, respectively, under these facilities.
Under the aforementioned credit agreement, WMECO may borrow at fixed or
variable rates plus an applicable margin based upon certain debt ratings, as
rated by the lower of Standard and Poor's or Moody's Investors Service. The
weighted average interest rates on WMECO's notes payable to banks outstanding
on December 31, 2002 and 2001, were 4.25 percent and 2.98 percent,
respectively.
This credit agreement provides that WMECO must comply with certain financial
and non-financial covenants as are customarily included in such agreements,
including, but not limited to, consolidated debt ratios and interest coverage
ratios. WMECO currently is and expects to remain in compliance with these
covenants.
Money Pool: Certain subsidiaries of NU, including WMECO, are members of the
Northeast Utilities System Money Pool (Pool). The Pool provides a more
efficient use of the cash resources of NU and reduces outside short-term
borrowings. NUSCO administers the Pool as agent for the member companies.
Short-term borrowing needs of the member companies are first met with
available funds of other member companies, including funds borrowed by NU
parent. NU parent may lend to the Pool but may not borrow. Funds may be
withdrawn from or repaid to the Pool at any time without prior notice.
Investing and borrowing subsidiaries receive or pay interest based on the
average daily federal funds rate. Borrowings based on loans from NU parent,
however, bear interest at NU parent's cost and must be repaid based upon the
terms of NU parent's original borrowing. At December 31, 2002 and 2001,
WMECO had $85.9 million and $9.2 million, respectively, of borrowings from
the Pool. The interest rate on borrowings from the Pool at December 31, 2002
and 2001, was 1.2 percent and 1.5 percent, respectively.
3. Pension Benefits and Postretirement Benefits Other Than Pensions
Pension Benefits: WMECO participates in a uniform noncontributory defined
benefit retirement plan (Plan) covering substantially all regular NU
employees. Benefits are based on years of service and the employees' highest
eligible compensation during 60 consecutive months of employment. Pre-tax
pension income, approximately 30 percent of which was credited to utility
plant, was $12.1 million in 2002, $13.7 million in 2001 and $12.4 million in
2000. These amounts exclude pension settlements, curtailments and net
special termination expenses of $1.2 million in income in 2002, $0.3 million
in expense in 2001 and $6.6 million in income in 2000. Pension income
attributable to earnings is as follows:
- --------------------------------------------------------------------------
For Years Ended December 31,
- --------------------------------------------------------------------------
(Millions of Dollars) 2002 2001 2000
- --------------------------------------------------------------------------
Pension income before
settlements, curtailments
and special termination benefits $(12.1) $(13.7) $(12.4)
Net pension income
capitalized as utility plant (a) 3.6 4.1 3.7
- --------------------------------------------------------------------------
Net pension income before
settlements, curtailments
and special termination benefits (8.5) (9.6) (8.7)
Settlements, curtailments and
special termination benefits
reflected in earnings - 0.7 -
- --------------------------------------------------------------------------
Total pension income
included in earnings $ (8.5) $ (8.9) $ (8.7)
- --------------------------------------------------------------------------
(a) Net pension income capitalized as utility plant was calculated
utilizing an average of 30 percent.
In conjunction with the Voluntary Separation Program (VSP) that was announced
in December 2000, WMECO recorded $0.2 million in settlement income. The VSP
was intended to reduce the generation-related support staff between March 1,
2001 and February 28, 2002, and was available to non-bargaining unit
employees who, by February 1, 2002, were at least age 50, with a minimum of
five years of credited service, and at December 15, 2000, were assigned to
certain groups and in eligible job classifications.
One component of the VSP included special pension termination benefits equal
to the greater of five years added to both age and credited service of
eligible participants or two weeks of pay for each year of service subject to
a minimum level of 12 weeks and a maximum of 52 weeks for eligible
participants. The special pension termination benefits expense associated
with the VSP totaled $0.5 million in 2001. The net total of the settlement
and curtailment income and the special termination benefits expense was $0.3
million, of which $0.7 million of costs were included in operating expenses
and $0.4 million was deferred as a regulatory liability and has been returned
to customers.
Additionally, in conjunction with the divestiture of its generation assets,
WMECO recorded $1.2 million in curtailment income in 2002 and $6.6 million of
curtailment income in 2000.
Postretirement Benefits Other Than Pensions (PBOP): The NU subsidiaries,
including WMECO, also provide certain health care benefits, primarily medical
and dental, and life insurance benefits through a benefit plan to retired
employees. These benefits are available for employees retiring from NU who
have met specified service requirements. For current employees and certain
retirees, the total benefit is limited to two times the 1993 per retiree
health care cost. These costs are charged to expense over the estimated work
life of the employee. WMECO annually funds postretirement costs through
external trusts with amounts that have been rate-recovered and which also are
tax deductible.
In 2001, WMECO recorded PBOP special termination benefits expense of $0.1
million in connection with the VSP. This amount was recorded as a regulatory
asset and collected through regulated utility rates in 2002.
Additionally, in conjunction with the divestiture of its generation assets,
WMECO recorded $0.4 million in special termination benefits income in 2000.
In 2002, the PBOP plan was amended to change the claims experience basis, to
increase minimum retiree contributions and to reduce the cap on the company's
subsidy to the dental plan. These amendments resulted in a $2.8 million
decrease in WMECO's benefit obligation under the PBOP plan at December 31,
2002.
The following table represents information on the plans' benefit obligation,
fair value of plan assets, and the respective plans' funded status:
<Table>
<Caption>
- ------------------------------------------------------------------------------------------------
At December 31,
- ------------------------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- ------------------------------------------------------------------------------------------------
(Millions of Dollars) 2002 2001 2002 2001
- ------------------------------------------------------------------------------------------------
Change in benefit obligation
Benefit obligation at beginning of year $(121.3) $(121.1) $(35.5) $(29.3)
Service cost (2.2) (1.9) (0.4) (0.4)
Interest cost (8.7) (8.5) (2.9) (2.4)
Plan amendment (1.1) - 2.8 -
Transfers (0.2) 4.9 (4.8) -
Actuarial loss (8.2) (3.0) (4.2) (7.0)
Benefits paid - excluding lump sum payments 8.1 8.0 3.6 3.6
Benefits paid - lump sum payments - 0.7 - -
Curtailments and settlements - 0.1 - -
Special termination benefits - (0.5) - -
- ------------------------------------------------------------------------------------------------
Benefit obligation at end of year $(133.6) $(121.3) $(41.4) $(35.5)
- ------------------------------------------------------------------------------------------------
Change in plan assets
Fair value of plan assets at beginning of year $ 191.2 $ 214.3 $ 14.7 $ 17.3
Actual return on plan assets (20.9) (9.5) (1.5) (1.6)
Employer contribution - - 3.6 2.6
Benefits paid - excluding lump sum payments (8.1) (8.0) (3.6) (3.6)
Benefits paid - lump sum payments - (0.7) - -
Transfers 0.2 (4.9) 2.2 -
- ------------------------------------------------------------------------------------------------
Fair value of plan assets at end of year $ 162.4 $ 191.2 $ 15.4 $ 14.7
- ------------------------------------------------------------------------------------------------
Funded status at December 31 $ 28.8 $ 69.9 $(26.0) $(20.8)
Unrecognized transition (asset)/obligation (0.5) (0.7) 13.8 17.4
Unrecognized prior service cost 6.4 6.0 (0.7) -
Unrecognized net loss/(gain) 32.8 (21.0) 11.7 3.8
- ------------------------------------------------------------------------------------------------
Prepaid/(accrued) benefit cost $ 67.5 $ 54.2 $ (1.2) $ 0.4
- ------------------------------------------------------------------------------------------------
</Table>
The following actuarial assumptions were used in calculating the plans' year
end funded status:
- -------------------------------------------------------------------------------
At December 31,
- -------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- -------------------------------------------------------------------------------
2002 2001 2002 2001
- -------------------------------------------------------------------------------
Discount rate 6.75% 7.25% 6.75% 7.25%
Compensation/progression rate 4.00% 4.25% 4.00% 4.25%
Health care cost trend rate (a) N/A N/A 10.00% 11.00%
- -------------------------------------------------------------------------------
(a) The annual per capita cost of covered health care benefits was assumed to
decrease to 5.00 percent by 2007.
The components of net periodic benefit (income)/expense are:
<Table>
<Caption>
- -----------------------------------------------------------------------------------------------------
For the Years Ended December 31,
- -----------------------------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- -----------------------------------------------------------------------------------------------------
(Millions of Dollars) 2002 2001 2000 2002 2001 2000
- -----------------------------------------------------------------------------------------------------
Service cost $ 2.2 $ 1.9 $ 2.2 $ 0.4 $ 0.4 $ 0.4
Interest cost 8.7 8.5 8.9 2.9 2.3 2.2
Expected return on plan assets (19.9) (20.0) (19.0) (1.5) (1.4) (1.3)
Amortization of unrecognized net
transition (asset)/obligation (0.2) (0.2) (0.2) 1.5 1.6 1.6
Amortization of prior service cost 0.7 0.6 0.6 - - -
Amortization of actuarial gain (3.6) (4.5) (4.9) - - -
Other amortization, net - - - 0.2 (0.4) (0.4)
- -----------------------------------------------------------------------------------------------------
Net periodic (income)/expense - before
settlements, curtailments and special
termination benefits (12.1) (13.7) (12.4) 3.5 2.5 2.5
- -----------------------------------------------------------------------------------------------------
Settlement income - (0.2) - - - -
Curtailment income (1.2) - (6.6) - - -
Special termination benefits expense/(income) - 0.5 - - 0.1 (0.4)
- -----------------------------------------------------------------------------------------------------
Total - settlements, curtailments and special
termination benefits (1.2) 0.3 (6.6) - 0.1 (0.4)
- -----------------------------------------------------------------------------------------------------
Total - net periodic (income)/expense $(13.3) $(13.4) $(19.0) $ 3.5 $ 2.6 $ 2.1
- -----------------------------------------------------------------------------------------------------
</Table>
For calculating pension and postretirement benefit costs, the following
assumptions were used:
<Table>
<Caption>
- -----------------------------------------------------------------------------------------
For the Years Ended December 31,
- -----------------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- -----------------------------------------------------------------------------------------
2002 2001 2000 2002 2001 2000
- -----------------------------------------------------------------------------------------
Discount rate 7.25% 7.50% 7.75% 7.25% 7.50% 7.75%
Expected long-term rate of return 9.25% 9.50% 9.50% N/A N/A N/A
Compensation/progression rate 4.25% 4.50% 4.75% 4.25% 4.50% 4.75%
Long-term rate of return -
Health assets, net of tax N/A N/A N/A 7.25% 7.50% 7.50%
Life assets N/A N/A N/A 9.25% 9.50% 9.50%
- -----------------------------------------------------------------------------------------
</Table>
Assumed health care cost trend rates have a significant effect on the amounts
reported for the health care plans. The effect of changing the assumed
health care cost trend rate by one percentage point in each year would have
the following effects:
- --------------------------------------------------------------------------
One Percentage One Percentage
(Millions of Dollars) Point Increase Point Decrease
- --------------------------------------------------------------------------
Effect on total service and
interest cost components $0.1 $(0.1)
Effect on postretirement
benefit obligation $1.3 $(1.1)
- --------------------------------------------------------------------------
Currently, WMECO's policy is to annually fund an amount at least equal to
that which will satisfy the requirements of the Employee Retirement Income
Security Act and Internal Revenue Code.
Pension and trust assets are invested primarily in domestic and international
equity securities and bonds.
The trust holding the postretirement health plan assets is subject to federal
income taxes.
4. Nuclear Generation Asset Divestitures
VYNPC: On July 31, 2002, VYNPC consummated the sale of its nuclear
generating plant to a subsidiary of Entergy Corporation (Entergy) for
approximately $180 million. As part of the sale, Entergy assumed
responsibility for decommissioning VYNPC's nuclear generating unit. Under
the terms of the sale, WMECO will continue to buy 2.5 percent of the plant's
output through March 2012 at a range of fixed prices.
Millstone: On March 31, 2001, WMECO and CL&P consummated the sale of
Millstone 1 and 2 to a subsidiary of Dominion Resources, Inc. (Dominion).
WMECO, CL&P and PSNH sold their ownership interests in Millstone 3 to
Dominion along with all of the unaffiliated joint ownership interests in
Millstone 3. WMECO received approximately $175 million of cash proceeds from
the sale and applied the proceeds to taxes and reductions of debt and equity.
As part of the sale, Dominion assumed responsibility for decommissioning the
three Millstone units. In connection with the sale, WMECO recorded a gain in
the amount of approximately $119.8 million, which was used to offset stranded
costs.
5. Commitments and Contingencies
A. Restructuring and Rate Matters
On March 30, 2001, WMECO filed its second annual stranded cost reconciliation
with the DTE for calendar year 2000. On March 29, 2002, WMECO filed its 2001
annual transition cost reconciliation with the DTE. This filing reconciled
the recovery of stranded generation costs for calendar year 2001 and includes
sales proceeds from WMECO's portion of the Millstone units, the impact of
securitization and approximately a $13 million benefit to ratepayers from
WMECO's nuclear performance-based ratemaking process.
WMECO and the office of the Massachusetts Attorney General reached a
settlement resolving all transition charge issues for the 1998 through 2001
reconciliations. The DTE approved this settlement on December 27, 2002. The
settlement had a positive impact of $9 million on WMECO 2002 pre-tax
earnings.
B. Environmental Matters
WMECO, is subject to environmental laws and regulations intended to mitigate
or remove the effect of past operations and improve or maintain the quality
of the environment. As such, WMECO has active environmental auditing and
training programs and believes it is substantially in compliance with the
current laws and regulations.
However, the normal course of operations may involve activities and
substances that expose WMECO to potential liabilities of which management
cannot determine the outcome. Additionally, management cannot determine the
outcome for liabilities that may be imposed for past acts, even though such
past acts may have been lawful at the time they occurred. Management does
not believe, however, that this will have a material impact on WMECO's
consolidated financial statements.
Based upon currently available information for the estimated remediation
costs as of December 31, 2002 and 2001, the liability recorded by WMECO for
its estimated environmental remediation costs amounted to $0.8 million and
$5.3 million, respectively.
C. Spent Nuclear Fuel Disposal Costs
Under the Nuclear Waste Policy Act of 1982, WMECO must pay the DOE for the
disposal of spent nuclear fuel and high-level radioactive waste. The DOE is
responsible for the selection and development of repositories for, and the
disposal of, spent nuclear fuel and high-level radioactive waste. For
nuclear fuel used to generate electricity prior to April 7, 1983 (Prior
Period Fuel), an accrual has been recorded for the full liability and payment
must be made prior to the first delivery of spent fuel to the DOE. Until
such payment is made, the outstanding balance will continue to accrue
interest at the 3-month treasury bill yield rate. As of December 31, 2002
and 2001, fees due to the DOE for the disposal of Prior Period Fuel were
$48.2 million and $47.4 million, respectively, including interest costs of
$32.6 million and $31.8 million, respectively.
Fees for nuclear fuel burned on or after April 7, 1983, were billed currently
to customers and paid to the DOE on a quarterly basis. At December 31, 2002,
as WMECO's ownership share of Millstone has been sold, WMECO is no longer
responsible for fees relating to current fuel burned at this facility.
D. Nuclear Insurance Contingencies
In conjunction with the divestiture of Millstone in 2001, NU and WMECO
terminated their nuclear insurance related to these plants, and WMECO has no
further exposure for potential assessments related to Millstone. However,
through its continuing association with Nuclear Electric Insurance Limited
(NEIL) and CYAPC and VYNPC, NU is subject to potential retrospective
assessments totaling $0.8 million under its respective NEIL insurance
policies.
E. Long-Term Contractual Arrangements
VYNPC: Previously, under the terms of its agreement, WMECO paid its
ownership (or entitlement) shares of costs, which included depreciation,
operation and maintenance (O&M) expenses, taxes, the estimated cost of
decommissioning, and a return on invested capital to VYNPC and recorded these
costs as purchased-power expenses. On July 31, 2002, VYNPC consummated the
sale of its nuclear generating unit to a subsidiary of Entergy for
approximately $180 million. Under the terms of the sale, WMECO will continue
to buy approximately 2.5 percent of the plant's output through March 2012 at
a range of fixed prices. The total cost of purchases under contracts with
VYNPC amounted to $4.3 million in 2002, $4.1 million in 2001 and $4 million
in 2000.
Electricity Procurement Contract: WMECO entered into an arrangement for the
purchase of electricity. The total cost of purchases under this arrangement
amounted to $2.5 million in 2002, $14.5 million in 2001 and $28.5 million in
2000. These amounts are for independent power producer contracts and do not
include contractual commitments related to WMECO's standard offer and default
service.
Hydro-Quebec: Along with other New England utilities, WMECO has entered into
an agreement to support transmission and terminal facilities to import
electricity from the Hydro-Quebec system in Canada. WMECO is obligated to
pay, over a 30-year period ending in 2020, its proportionate share of the
annual O&M expenses and capital costs of those facilities.
Estimated Future Annual Costs: The estimated future annual costs of WMECO's
significant long-term contractual arrangements are as follows:
- -------------------------------------------------------------------------------
(Millions of Dollars) 2003 2004 2005 2006 2007
- -------------------------------------------------------------------------------
VYNPC $ 4.8 $ 4.6 $4.2 $4.4 $4.3
Electricity Procurement Contract 2.8 2.8 2.8 2.8 2.8
Hydro-Quebec 3.0 2.9 2.9 2.6 2.5
- -------------------------------------------------------------------------------
Totals $10.6 $10.3 $9.9 $9.8 $9.6
- -------------------------------------------------------------------------------
F. Nuclear Decommissioning and Plant Closure Costs
In conjunction with the Millstone and VYNPC nuclear generation asset
divestitures, the applicable liabilities and nuclear decommissioning trusts
were transferred to the purchasers and the purchasers agreed to assume
responsibility for decommissioning their respective units.
During 2002, NU, along with the other joint owners, were notified by the
Yankee Companies that the estimated cost of decommissioning the units owned
by CYAPC, YAEC and MYAPC increased in total by approximately $380 million
over prior estimates due to higher anticipated costs for spent fuel storage,
security and liability and property insurance. WMECO's share of this
increase totals $32.4 million. Following rate cases to be filed by the
Yankee Companies with the FERC, NU will seek recovery of the higher
decommissioning costs from retail customers through the appropriate state
regulatory agency. At December 31, 2002 and 2001, WMECO's remaining
estimated obligations, for decommissioning for the units owned by CYAPC, YAEC
and MYAPC, which have been shut down, were $63.8 million and $37.4 million,
respectively.
6. Fair Value of Financial Instruments
The following methods and assumptions were used to estimate the fair value of
each of the following financial instruments:
Long-Term Debt and Rate Reduction Bonds: The fair value of WMECO's fixed-
rate securities is based upon the quoted market price for those issues or
similar issues. Adjustable rate securities are assumed to have a fair value
equal to their carrying value. The carrying amounts of WMECO's financial
instruments and the estimated fair values are as follows:
- -------------------------------------------------------------------------------
At December 31, 2002
- -------------------------------------------------------------------------------
(Millions of Dollars) Carrying Amount Fair Value
- -------------------------------------------------------------------------------
Long-term debt -
Other long-term debt $102.0 $104.3
Rate reduction bonds 142.7 159.2
- -------------------------------------------------------------------------------
- -------------------------------------------------------------------------------
At December 31, 2001
- -------------------------------------------------------------------------------
(Millions of Dollars) Carrying Amount Fair Value
- -------------------------------------------------------------------------------
Long-term debt -
Other long-term debt $101.2 $101.0
Rate reduction bonds 152.3 154.1
- -------------------------------------------------------------------------------
Other Financial Instruments: The carrying value of financial instruments
included in current assets and current liabilities, approximates their fair
value.
7. Leases
WMECO has entered into lease agreements for the use of data processing and
office equipment, vehicles, nuclear control room simulators, and office
space. The provisions of these lease agreements generally provide for
renewal options.
Capital lease rental payments charged to operating expense were $1.9 million
and $9.6 million for 2001 and 2000, respectively. Interest included in
capital lease rental payments was $0.7 million in 2001 and $2.8 million in
2000. Operating lease rental payments charged to expense were $2.3 million
in 2002, $2.5 million in 2001, and $3.2 million in 2000.
Future minimum rental payments, excluding executory costs such as property
taxes, state use taxes, insurance, and maintenance, under long-term
noncancelable operating leases, as of December 31, 2002, are as follows:
- -----------------------------------------------------------
Year
- -----------------------------------------------------------
(Millions of Dollars)
- -----------------------------------------------------------
2003 $ 3.5
2004 3.4
2005 3.2
2006 2.9
2007 2.3
After 2007 10.5
- -----------------------------------------------------------
Future minimum lease payments $25.8
- -----------------------------------------------------------
8. Accumulated Other Comprehensive Income/(Loss)
The accumulated balance for each other comprehensive income/(loss) item is as
follows:
- --------------------------------------------------------------------------
Current
December 31, Period December 31,
(Millions of Dollars) 2001 Change 2002
- --------------------------------------------------------------------------
Unrealized
gains/(losses)
on securities $0.1 $(0.1) $ -
Minimum pension
liability adjustments - (0.1) (0.1)
- --------------------------------------------------------------------------
Accumulated other
comprehensive
income/(loss) $0.1 $(0.2) $(0.1)
- --------------------------------------------------------------------------
- --------------------------------------------------------------------------
Current
December 31, Period December 31,
(Millions of Dollars) 2000 Change 2001
- --------------------------------------------------------------------------
Unrealized
gains/(losses)
on securities $0.2 $0.1 $0.1
- --------------------------------------------------------------------------
Accumulated other
comprehensive
income/(loss) $0.2 $0.1 $0.1
- --------------------------------------------------------------------------
The changes in the components of other comprehensive income/(loss) are reported
net of the following income tax effects:
- --------------------------------------------------------------------------
(Millions of Dollars) 2002 2001 2000
- --------------------------------------------------------------------------
Unrealized
gains/(losses)
on securities $0.1 $0.1 $ -
Minimum pension
liability adjustments - - -
- --------------------------------------------------------------------------
Accumulated other
comprehensive
income/(loss) $0.1 $0.1 $ -
- --------------------------------------------------------------------------
9. Long-Term Debt
Details of long-term debt outstanding are as follows:
- --------------------------------------------------------------------------
At December 31, 2002 2001
- --------------------------------------------------------------------------
(Millions of Dollars)
Pollution Control Notes:
Tax Exempt 1993 Series A,
5.85% due 2028 $ 53.8 $ 53.8
Fees and interest due for spent
nuclear fuel disposal costs 48.2 47.4
Less amounts due within one year - -
- --------------------------------------------------------------------------
Long-term debt $102.0 $101.2
- --------------------------------------------------------------------------
WMECO has secured $53.8 million of pollution control notes with second
mortgage liens on transmission assets.
10. Income Tax Expense
The components of the federal and state income tax provisions are as follows:
- -------------------------------------------------------------------------------
For the Years Ended
December 31, 2002 2001 2000
- -------------------------------------------------------------------------------
(Millions of Dollars)
Current income taxes:
Federal $ 27.9 $ 0.3 $15.8
State 5.8 1.0 10.9
------ ----- -----
Total current 33.7 1.3 26.7
------ ----- -----
Deferred income taxes, net:
Federal (13.5) 5.3 (0.8)
State 0.1 0.6 (8.6)
------ ----- -----
Total deferred (13.4) 5.9 (9.4)
------ ----- -----
Investment tax credits, net (13.5) (0.6) (2.1)
- -------------------------------------------------------------------------------
Total income tax expense $ 6.8 $ 6.6 $15.2
- -------------------------------------------------------------------------------
Deferred income taxes are comprised of the tax effects of temporary
differences as follows:
- -------------------------------------------------------------------------------
For the Years Ended
December 31, 2002 2001 2000
- -------------------------------------------------------------------------------
(Millions of Dollars)
Depreciation, leased nuclear
fuel, settlement credits and
disposal costs $ 1.5 $ (0.6) $ 0.9
Regulatory deferral (6.0) (3.7) (16.4)
Sale of generation assets (2.0) (30.5) -
Pension accruals 2.6 1.0 5.9
Securitized contract
termination
costs and other (3.6) 38.4 -
Other (5.9) 1.3 0.2
- -------------------------------------------------------------------------------
Deferred income taxes, net $(13.4) $ 5.9 $ (9.4)
- -------------------------------------------------------------------------------
A reconciliation between income tax expense and the expected tax expense at
the statutory rate is as follows:
- -------------------------------------------------------------------------------
For the Years Ended
December 31, 2002 2001 2000
- -------------------------------------------------------------------------------
(Millions of Dollars)
Expected federal income tax $15.5 $ 7.5 $17.6
Tax effect of differences:
Depreciation 0.5 - (1.2)
Amortization of
regulatory assets - 1.2 1.3
Investment tax credit
amortization (13.5) (0.6) (2.1)
State income taxes,
net of federal benefit 3.8 1.1 1.5
Other, net 0.5 (2.6) (1.9)
- -------------------------------------------------------------------------------
Total income tax expense $ 6.8 $ 6.6 $15.2
- -------------------------------------------------------------------------------
11. Segment Information
NU is organized between regulated utilities (electric and gas since the
March 1, 2000 acquisition of Yankee) and competitive energy subsidiaries.
WMECO is included in the regulated utilities segment of NU and has no other
reportable segments.
<Table>
<Caption>
- ---------------------------------------------------------------------------------------------------
Selected Consolidated Financial Data
- ---------------------------------------------------------------------------------------------------
(Thousands of Dollars) 2002 2001 2000 1999 1998
- ---------------------------------------------------------------------------------------------------
Operating Revenues $369,487 $478,869 $ 513,678 $ 414,231 $ 393,322
Net Income/(Loss) 37,682 14,968 35,268 2,887 (9,579)
Cash Dividends on Common Stock 16,009 22,000 12,002 - -
Total Assets 836,661 852,662 1,047,818 1,253,604 1,287,682
Rate Reduction Bonds 142,742 152,317 - - -
Long-Term Debt (a) 101,991 101,170 199,425 290,279 389,314
Preferred Stock Not Subject to
Mandatory Redemption - - 20,000 20,000 20,000
Preferred Stock Subject to
Mandatory Redemption (a) - - 16,500 18,000 19,500
Obligations Under Capital Leases (a) 87 110 26,921 29,972 34,093
- ---------------------------------------------------------------------------------------------------
</Table>
- -------------------------------------------------------------------------------
Consolidated Quarterly Financial Data (Unaudited)
- -------------------------------------------------------------------------------
(Thousands of Dollars) Quarter Ended
- -------------------------------------------------------------------------------
2002 March 31 June 30 September 30 December 31
- -------------------------------------------------------------------------------
Operating Revenues $ 96,005 $ 87,191 $ 95,684 $ 90,607
Operating Income $ 15,695 $ 10,678 $ 12,524 $ 20,786
Net Income $ 6,890 $ 15,322 $ 4,730 $ 10,740
- -------------------------------------------------------------------------------
2001
- -------------------------------------------------------------------------------
Operating Revenues $143,300 $106,866 $120,679 $108,024
Operating Income $ 11,876 $ 6,406 $ 14,821 $ 4,786
Net Income $ 3,319 $ 1,518 $ 3,880 $ 6,251
- -------------------------------------------------------------------------------
(a) Includes portions due within one year.
- -------------------------------------------------------------------------------
Consolidated Statistics (Unaudited)
- -------------------------------------------------------------------------------
Gross Electric
Utility Plant Average Annual
December 31, Use Per Electric
(Thousands of kWh Sales Residential Customers Employees
Dollars) (a) (Millions) Customer (kWh) (Average) December 31,
- -------------------------------------------------------------------------------
2002 $ 602,013 4,102 7,921 203,760 400
2001 583,183 4,712 7,476 200,166 405
2000 1,153,514 7,278 7,371 198,372 406
1999 1,216,015 4,654 7,423 198,012 482
1998 1,256,046 4,009 6,979 196,339 533
(a) Amount includes construction work in progress.