EXHIBIT 13.4
2002 Annual Report
Public Service Company of New Hampshire and Subsidiaries
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.............................................. 8
Consolidated Balance Sheets....................................... 10-11
Consolidated Statements of Income................................. 12
Consolidated Statements of Comprehensive Income................... 12
Consolidated Statements of Common Stockholder's Equity............ 13
Consolidated Statements of Cash Flows............................. 14
Notes to Consolidated Financial Statements........................ 15
Selected Consolidated Financial Data.............................. 24
Consolidated Quarterly Financial Data (Unaudited)................. 24
Consolidated Statistics (Unaudited)............................... 25
Preferred Stockholder and Bondholder Information.................. Back Cover
Management's Discussion and Analysis
Financial Condition
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Overview
Public Service Company of New Hampshire (PSNH or the company), a wholly owned
subsidiary of Northeast Utilities (NU), earned $62.9 million in 2002 compared
with $81.8 million in 2001. The lower 2002 net income was largely due to an
after-tax gain of $15.5 million PSNH recorded in 2001 as a result of the sale
of PSNH's share of the Millstone 3 nuclear unit (Millstone). NU's other
subsidiaries include The Connecticut Light and Power Company (CL&P), Western
Massachusetts Electric Company (WMECO), Yankee Energy System, Inc., North
Atlantic Energy Corporation (NAEC), Select Energy, Inc., Northeast Generation
Company, Northeast Generation Services Company, and Select Energy Services,
Inc.
PSNH's revenues during 2002 decreased to $1 billion from $1.2 billion during
2001. The decrease in revenues primarily relates to lower retail and
wholesale revenues. Retail revenues decreased primarily due to an 11 percent
rate decrease that was effective May 1, 2001. Wholesale revenues decreased
due to a reduction in prices and a lower volume of bilateral transactions and
sales of excess capacity and energy.
Future Outlook
PSNH is expected to have reduced earnings in 2003 compared to 2002. The
primary reasons for the reduction in 2003 earnings include a significant
reduction in rate base due to the gain on the sale of Seabrook in 2002 and a
significant increase in the projected level of pension expense in 2003 and
forward. In addition, PSNH earnings are expected to be reduced due to the
2002 amortization of investment tax credits, the elimination of certain
operating reserves and the positive settlement of certain previously disputed
sales transactions in 2002.
PSNH recorded $0.6 million in pre-tax pension expense in 2002, approximately
35 percent of which was capitalized and reflected as an increase to the cost
of capital expenditures with the remainder being recognized in the
consolidated statements of income as operating expenses. In 2003, as a
result of continued poor performance in the equity markets, PSNH is
projecting the total level of pre-tax pension expense to increase to
approximately $7 million, with a similar percentage being reflected as a
increase to the cost of capital expenditures. Pension expense/income is
annually adjusted during the second quarter based upon updated actuarial
valuations, at which time the 2003 estimate may be modified.
Liquidity
On November 1, 2002, NAEC consummated the sale of its 35.98 percent ownership
interest in Seabrook. NAEC received approximately $331 million of total cash
proceeds from the sale of Seabrook. A portion of this cash was used to repay
all $90 million of NAEC's outstanding debt, to return a portion of NAEC's
equity to NU and will be used to pay approximately $95 million in taxes. The
remaining proceeds received by NAEC were refunded to PSNH through the
Seabrook Power Contracts.
In January 2002, PSNH issued an additional $50 million in rate reduction
bonds and used the proceeds to repay short-term debt that was incurred to
buyout a purchased-power contract in December 2001.
In November 2002, PSNH, 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. PSNH had no borrowings on this credit
line at December 31, 2002.
Rate reduction bonds are included on the consolidated balance sheets of PSNH,
even though the debt is nonrecourse to PSNH. At December 31, 2002, PSNH had
a total of $510.8 million in rate reduction bonds outstanding, compared with
$507.4 million outstanding at December 31, 2001. All outstanding rate
reduction bonds of PSNH are scheduled to be fully amortized by May 1, 2013.
Interest on the rate reduction bonds totaled $30.5 million in 2002, compared
with $20.7 million in 2001. Amortization of the rate reduction bonds totaled
$46.5 million in 2002, compared with $17.6 million in 2001. PSNH 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 PSNH, the three rating agencies that rate PSNH's debt do not
include the revenues, expenses, or outstanding securities related to the rate
reduction bonds in establishing the credit ratings of PSNH.
PSNH funded its capital expenditures through internally generated cash flows
and through proceeds returned from NAEC as a result of the sale of Seabrook.
PSNH returned $37 million in equity capital to NU in 2002. PSNH's capital
expenditures are expected to total $116.3 million in 2003 and remain largely
funded through internally generated cash flows.
PSNH's net cash flows provided by operating activities increased to $326
million in 2002, compared with $272.6 million in 2001. Cash flows provided
by operating activities increased primarily due to changes in working
capital, primarily accrued taxes and accounts payable, partially offset by
the decrease in net income in 2002. The increase in accrued taxes relates
primarily to the refund PSNH received from NAEC related to the gain on the
sale of Seabrook.
There was a lower level of financing activities in 2002 as compared to 2001,
primarily due to the issuance and retirements of long-term debt, issuance and
retirements of rate reduction bonds and the buyout of independent power
producer contracts in 2001. The level of common dividends totaled $45
million in 2002, as compared to $27 million in 2001.
Business Development and Capital Expenditures
The expectation that PSNH will retain its generation assets, at least through
2004, will result in higher near-term capital expenditures at PSNH. PSNH's
capital expenditures, excluding nuclear fuel, totaled $109.8 million in 2002,
compared with $92.6 million in 2001. Capital expenditures are expected to
total $116.3 million in 2003, as PSNH continues to upgrade and expand its
distribution and transmission system and upgrade its generation plants. The
expenditures will be funded primarily through internally generated cash
flows.
On December 5, 2002, PSNH announced an agreement to acquire the franchise and
electric system of Connecticut Valley Electric Company, Inc. (CVEC), a
subsidiary of Central Vermont Public Service Corporation (CVPS) that serves
approximately 10,000 customers in western New Hampshire. Under the
agreement, PSNH will pay CVPS approximately $9 million for its assets and an
additional $21 million to terminate a wholesale power contract between CVPS
and CVEC. Customers of CVEC will become customers of PSNH, whose residential
rates are now approximately 20 percent lower than those of CVEC. PSNH will
be allowed to recover the $21 million payment with a return consistent with
Part 3 stranded cost treatment under the "Agreement to Settle PSNH
Restructuring" (Restructuring Settlement). Part 3 stranded costs are
nonsecuritized regulatory assets which must be recovered by a recovery end
date determined in accordance with the Restructuring Settlement or be written
off. The sale agreement is supported by the New Hampshire Governor's Office,
New Hampshire Public Utilities Commission (NHPUC) staff, the state Office of
Consumer Advocate, the City of Claremont, and New Hampshire Legal Assistance.
The Federal Energy Regulatory Commission (FERC) and the NHPUC must approve
the sale, which is expected to become effective on January 1, 2004.
Regional Transmission Organization
The FERC has required all transmission owning utilities, including PSNH, to
voluntarily start forming Regional Transmission Organizations (RTO) or to
state why this process has not begun.
PSNH 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 PSNH's
return on equity as a result of this rate case cannot be estimated at this
time. At December 31, 2002, PSNH capitalized $0.3 million related to RTO
formation activities.
Restructuring and Rate Matters
In July 2001, the NHPUC opened a docket to review the fuel and purchased-
power adjustment clause (FPPAC) costs incurred between August 2, 1999 and
April 30, 2001. Under the Restructuring Settlement, FPPAC deferrals are
recovered as a Part 3 stranded cost through the stranded cost recovery
charge. On December 31, 2002, the NHPUC issued its final order allowing
recovery of virtually all such costs.
On June 28, 2002, PSNH made its first stranded cost recovery charge
reconciliation filing with the NHPUC for the period May 1, 2001, through
December 31, 2001. This filing reconciles stranded cost revenues against
actual stranded cost charges with any difference being credited against
stranded costs or deferred for future recovery. Included in the stranded
cost charges are the generation costs for the filing period. The generation
costs included in this filing were subject to a prudence review by the NHPUC.
In January 2003, PSNH entered into a settlement agreement with the Office of
Consumer Advocate and the staff of the NHPUC that resolved all outstanding
issues. In conjunction with the settlement agreement, the NHPUC staff
recommended no disallowances resulting from their review of the outages at
PSNH's generating plants. A final order approving the settlement agreement
was issued by the NHPUC in February 2003. The NHPUC order approved PSNH's
reconciliation of stranded costs as outlined within the settlement agreement
and had no impact on PSNH's earnings.
On September 12, 2002, the NHPUC issued a final decision approving the
auction results in the sale of Seabrook to FPL. On November 1, 2002, the
sale was consummated. The proceeds received by NAEC, after NAEC repaid its
outstanding debt, were refunded to PSNH through the Seabrook Power Contracts.
PSNH used the proceeds received from NAEC to recover stranded costs and repay
debt with the remaining proceeds to be returned to NU. As a result of the
Seabrook sale, PSNH expects its wholesale electric sales to decline
significantly in 2003. However, PSNH expects to generate most of the
electricity it needs to serve retail customers from its own generating plants
or purchased-power obligations and to purchase the remainder in the wholesale
market.
On February 1, 2003, in accordance with the Restructuring Settlement, PSNH
raised the transition service rate for residential and small commercial
customers to $0.0460 per kWh from $0.0440 per kWh. On the same date, PSNH
also raised its transition service rate for large commercial and industrial
customers to $0.0467 per kWh from $0.0440 per kWh. PSNH expects these rates
to be adequate to recover its generation and purchased-power costs, including
the recovery of carrying costs on PSNH's generation investment. If
recoveries exceed PSNH's costs, those overrecoveries will be credited against
PSNH's Part 3 stranded cost balance. If actual costs exceed those
recoveries, PSNH will defer those costs for future recovery from customers
through its Stranded Cost Recovery Charge.
PSNH's delivery rates are fixed until February 1, 2004. Under the
Restructuring Settlement, PSNH must file a rate case by December 31, 2003,
for the purpose of commencing a review of PSNH's delivery rates. Also, under
New Hampshire electric industry restructuring statutes, PSNH cannot divest
its nonnuclear generation assets until at least February 1, 2004. At this
time, management does not expect PSNH to propose selling its 1,200 megawatts
of generation assets.
For further information regarding commitments and contingencies related to
restructuring, see Note 6A, "Commitments and Contingencies - Restructuring
and Rate Matters," to the consolidated financial statements.
Nuclear Generation Asset Divestitures
Seabrook: On November 1, 2002, CL&P, NAEC, and certain other joint owners
consummated the sale of their ownership interest in Seabrook. NAEC formerly
sold all of its entitlement in Seabrook to PSNH and billed PSNH all costs
related to the entitlement under the terms of the Seabrook Power Contracts.
VYNPC: On July 31, 2002, Vermont Yankee Nuclear Power Corporation (VYNPC)
consummated the sale of its nuclear generating unit. PSNH owns 4.3 percent
of VYNPC.
Millstone: On March 31, 2001, PSNH, CL&P and WMECO 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 these divestitures and nuclear decommissioning, see
Note 5, "Nuclear Generation Asset Divestitures," and Note 6E, "Nuclear
Decommissioning and Plant Closure 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
PSNH. The following describes accounting policies and estimates that
management believes are the most critical in nature:
Presentation: In accordance with current accounting pronouncements, PSNH'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. PSNH
has less than 50 percent ownership interests in the Connecticut Yankee Atomic
Power Company, Yankee Atomic Electric Company, Maine Yankee Atomic Power
Company, VYNPC, and two companies that transmit electricity imported from the
Hydro-Quebec system, which are classified as variable interest entities under
Financial Accounting Standards Board Interpretation No. 46, "Consolidation of
Variable Interest Entities," and for which PSNH 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 PSNH's
consolidated financial statements.
Revenue Recognition: Revenues are based on rates approved by the NHPUC.
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 NHPUC.
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 PSNH
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." PSNH's transmission,
distribution and generation businesses continue to be cost-of-service rate
regulated, and management believes the application of SFAS No. 71 continues
to be appropriate.
On May 22, 2001, the Governor of New Hampshire signed a bill modifying the
state's electric utility industry restructuring laws delaying the sale of
PSNH's fossil and hydroelectric generation assets until at least February 1,
2004. Since then there has been no regulatory action, and management
currently has no plans to divest these generation assets. The NHPUC has
allowed and is expected to continue to allow rate recovery of a return of and
on these generation assets, as well as all operating expenses.
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
these businesses no longer meets the criteria of regulatory accounting under
SFAS No. 71, that portion of the company will have to discontinue regulatory
accounting and write off regulatory assets. Such a write-off could have a
material impact on PSNH'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 PSNH's consolidated
financial statements. Management believes it is probable that PSNH will
recover its investments in long-lived assets, including regulatory assets.
Pension and Postretirement Benefit Obligations: PSNH 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 PSNH's consolidated
financial statements.
PSNH's pre-tax periodic pension expense/income for the Plan, excluding
settlements, curtailments, and special termination benefits, totaled $0.6
million in expense and $3.9 million in income for the years ended December 31,
2002 and 2001, respectively. Pension expense or 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. PSNH expects to use a long-term rate of return assumption of 8.75
percent for 2003. The pension expense/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 and
Seabrook nuclear units. Net SFAS No. 88 expenses totaled $1.3 million for
the year ended December 31, 2001. Approximately 35 percent of net pension
expense/income is capitalized as additions or reductions to capital additions
to utility plant.
In developing the expected long-term rate of return assumption, PSNH
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 NU regularly reviews the actual asset allocations and
periodically rebalances the investments to the targeted allocation when
appropriate. NU 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. PSNH believes that
8.75 percent is a reasonable long-term rate of return on Plan assets for
2003. PSNH will continue to evaluate the actuarial assumptions, including
the expected rate of return, at least annually, and will adjust the
appropriate assumptions as necessary.
PSNH 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, PSNH's portion of the Plan had cumulative unrecognized
investment losses of $50.9 million, which will increase Plan expense over the
next four years by reducing the expected return on Plan assets. At December
31, 2002, PSNH's portion of the Plan also had cumulative unrecognized
actuarial gains of $8.2 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 $42.7 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, PSNH estimates that pension
expense for the Plan will be approximately $7 million, approximately $11
million and approximately $15 million 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 PSNH's portion of the Plan assets has decreased from $196.6
million at December 31, 2001 to $163.5 million at December 31, 2002. The
investment performance returns and declining discount rates have reduced the
funded status of PSNH's portion of the Plan, on a projected benefit
obligation (PBO) basis, from an underfunded position of $31.3 million at
December 31, 2001 to $97.4 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. PSNH 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, PSNH 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 PSNH'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. PSNH 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. PSNH 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, PSNH has
established a regulatory asset. This asset amounted to $96.5 million and
$87.9 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 PSNH's consolidated financial statements.
Environmental Matters: At December 31, 2002, PSNH has recorded a reserve for
various environmental liabilities. PSNH'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. Changes in future cost estimates will
have a smaller impact on PSNH, because they have a regulatory mechanism in
place to recover environmental remediation costs.
Special Purpose Entities: PSNH has two special purpose entities, both of
which are currently consolidated in the financial statements. During 2001
and 2002, to facilitate the issuance of rate reduction bonds and certificates
intended to finance certain stranded costs, PSNH established PSNH Funding LLC
and PSNH Funding LLC 2 (the funding companies). The funding companies were
created as part of state sponsored securitization programs. The funding
companies are restricted from engaging in non-related activities and are
required to operate in a manner intended to reduce the likelihood that they
would be included in their respective parent company'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 4, "Pension Benefits and
Postretirement Benefits Other Than Pensions," Note 6B, "Commitments and
Contingencies - Environmental Matters," and Note 11, "Income Tax Expense," to
the consolidated financial statements.
Other Matters
Other Commitments and Contingencies: For further information regarding other
commitments and contingencies, see Note 6, "Commitments and Contingencies,"
to the consolidated financial statements.
Contractual Obligations and Commercial Commitments: Information regarding
PSNH's contractual obligations and commercial commitments at 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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Capital leases $ 0.5 $ 0.4 $ 0.4 $ 0.3 $ 0.2
Operating leases 4.6 4.1 3.4 3.1 1.7
Long-term contractual
arrangements 154.6 157.6 158.4 154.3 77.2
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Totals $159.7 $162.1 $162.2 $157.7 $79.1
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Rate reduction bond amounts are not included in this table. For further
information regarding NU's contractual obligations and commercial
commitments, see Note 8, "Leases," and Note 6D, "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,
volatility in electric and natural gas commodity markets, and other presently
unknown or unforeseen factors.
Results of Operations
The components of significant income statement variances for the past two
years are provided in the table below.
<Table>
<Caption>
- ---------------------------------------------------------------------------------------
2002 over/(under)2001 2001 over/(under) 2000
Income Statement Variances --------------------- ----------------------
(Millions of Dollars) Amount Percent Amount Percent
- ---------------------------------------------------------------------------------------
Operating Revenues $(125) (11)% $(120) (9)%
Operating Expenses:
Fuel, purchased and net
interchange power (326) (46) (140) (16)
Other operation 3 2 1 1
Maintenance 8 14 9 19
Depreciation 1 3 (4) (9)
Amortization of regulatory assets, net 174 (a) 20 43
Taxes other than income taxes (4) (11) (4) (9)
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Total operating expenses (144) (14) (118) (10)
- ---------------------------------------------------------------------------------------
Operating Income 19 14 (2) (1)
Interest expense, net (2) (4) 13 36
Other income/(loss), net (38) (a) 22 (a)
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Income before income tax expense (17) (14) 7 7
Income tax expense 2 4 (7) (15)
Income before extraordinary loss (19) (23) 14 21
Extraordinary loss - - 214 (a)
- ---------------------------------------------------------------------------------------
Net income/(loss) $ (19) (23)% $ 228 (a)%
=======================================================================================
</Table>
(a) Percent greater than 100.
Operating Revenues
Operating revenue decreased $125 million or 11 percent in 2002, primarily due
to lower retail and wholesale revenues. Retail revenues decreased $24
million, primarily due to the May 2001 rate decrease. Retail kilowatt-hour
sales were essentially flat with a 0.1 percent decrease. Wholesale revenues
decreased $100 million due to a reduction in prices and a lower volume of
bilateral transactions and sales of excess capacity and energy.
Operating revenue decreased $120 million or 9 percent in 2001, primarily due
to lower retail and wholesale revenues. Retail revenues decreased $75
million, primarily due to 5 and 11 percent rate decreases that were effective
October 1, 2000 and May 1, 2001, respectively ($89 million) as part of PSNH
restructuring, which was partially offset by higher retail sales ($14
million). Retail kilowatt-hour sales increased 1.2 percent. Wholesale
revenues decreased $43 million due to lower capacity and energy sales.
Fuel, Purchased and Net Interchange Power
Fuel, purchased and net interchange power expense decreased $326 million in
2002, primarily due to the gain on the sale of utility plant resulting from
the sale of Seabrook Station recorded on NAEC's books which was transferred
to PSNH through the Seabrook Power Contracts ($171 million), lower purchased
power from NAEC ($67 million), and lower expenses resulting from the decrease
in wholesale energy sales.
Fuel, purchased and net interchange power expense decreased in 2001,
primarily due to lower purchased power expenses and lower expenses from NAEC
as a result of the buydown of the Seabrook Power Contracts.
Other Operation and Maintenance
Other operation and maintenance (O&M) expenses increased $11 million in 2002,
primarily due to higher fossil/hydro production expense ($8 million) and
higher transmission and distribution expense ($3 million).
Other O&M expenses increased $10 million in 2001, primarily due to higher
fossil/hydro production expense ($12 million) and higher transmission and
distribution expense ($2 million), partially offset by lower nuclear expense
($2 million) and administrative and general expense ($1 million).
Depreciation
Depreciation increased $1 million in 2002, primarily due to the construction
of the new corporate headquarters.
Depreciation expense decreased in 2001, primarily due to the sale of
Millstone unit three at the end of the first quarter 2001.
Amortization of Regulatory Assets, Net
Amortization of regulatory assets, net increased $174 million primarily due
to recovery of stranded costs associated with the sale of the Seabrook
Station.
Amortization of regulatory assets, net increased in 2001, primarily due to
higher amortization related to restructuring.
Taxes Other Than Income Taxes
Taxes other than income taxes decreased $4 million in 2002, primarily due to
the discontinuance of New Hampshire franchise taxes in 2001.
Taxes other than income taxes decreased in 2001, primarily due to lower New
Hampshire franchise taxes in 2001.
Interest Expense, Net
Interest expense, net decreased in 2002 primarily due to the December 2001
refinancing of long-term debt at lower rates.
Interest expense, net increased in 2001 primarily due to interest associated
with the issuance of rate reduction bonds in 2001, partially offset by lower
interest on long-term debt resulting from the retirement and refinancing of
long-term debt.
Other Income/(Loss), Net
Other Income/(loss), net decreased in 2002 as a result of PSNH's sale of its
ownership in Millstone 3 in 2001 ($26 million), a gain on the disposition of
property in 2001 ($4 million) and lower dividend income in 2002 ($2 million).
Other Income/(loss), net increased in 2001 as a result of PSNH's sale of its
ownership in Millstone 3.
Income Tax Expense
Income tax expense increased in 2002 primarily as a result of reduced
investment tax credit amortization, partially offset by the tax consequences
of lower acquisition premium amortization. Income tax expense decreased in
2001, primarily due to the acceleration of investment tax credits associated
with Seabrook due to the expected sale.
Extraordinary Loss, Net of Tax Benefit
Extraordinary loss in 2000 is due to an after-tax write-off by PSNH of
approximately $225 million of stranded costs under the Restructuring
Settlement with the state of New Hampshire, combined with other positive
effects relating to the discontinuation of SFAS No. 71 ($11 million).
Independent Auditors' Report
- ----------------------------
To the Board of Directors of
Public Service Company of New Hampshire:
We have audited the accompanying consolidated balance sheet of Public Service
Company of New Hampshire and subsidiaries (a New Hampshire 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 Public Service Company of
New Hampshire and subsidiaries 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 Public Service Company of New Hampshire:
We have audited the accompanying consolidated balance sheets of Public
Service Company of New Hampshire and subsidiaries (a New Hampshire
corporation and a wholly owned subsidiary of Northeast Utilities) 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 Public Service Company of
New Hampshire and subsidiaries 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.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
<Table>
<Caption>
- ----------------------------------------------------------------------------------------------
At December 31, 2002 2001
- ----------------------------------------------------------------------------------------------
(Thousands of Dollars)
ASSETS
- ------
Current Assets:
Cash....................................................... $ 5,319 $ 1,479
Receivables, less provision for uncollectible
accounts of $1,990 in 2002 and $1,737 in 2001............ 68,204 70,540
Accounts receivable from affiliated companies.............. 9,667 13,055
Unbilled revenues.......................................... 32,004 29,268
Notes receivable from affiliated companies................. 23,000 -
Fuel, materials and supplies, at average cost.............. 49,182 42,047
Prepayments and other...................................... 10,032 10,211
----------- -----------
197,408 166,600
----------- -----------
Property, Plant and Equipment:
Electric utility........................................... 1,431,710 1,447,955
Other...................................................... 6,195 6,221
----------- -----------
1,437,905 1,454,176
Less: Accumulated depreciation.......................... 715,736 689,397
----------- -----------
722,169 764,779
Construction work in progress.............................. 50,547 44,961
----------- -----------
772,716 809,740
----------- -----------
Deferred Debits and Other Assets:
Regulatory assets.......................................... 859,871 1,046,760
Other ..................................................... 92,280 71,414
----------- -----------
952,151 1,118,174
----------- -----------
Total Assets................................................ $ 1,922,275 $ 2,094,514
=========== ===========
</Table>
The accompanying notes are an integral part of these consolidated financial
statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
<Table>
<Caption>
- ---------------------------------------------------------------------------------------------
At December 31, 2002 2001
- ---------------------------------------------------------------------------------------------
(Thousands of Dollars)
LIABILITIES AND CAPITALIZATION
- ------------------------------
Current Liabilities:
Notes payable to banks.................................... $ - $ 60,500
Notes payable to affiliated companies..................... - 23,000
Obligations under Seabrook Power Contracts
and other capital leases - current portion.............. 206 24,164
Accounts payable.......................................... 54,588 32,285
Accounts payable to affiliated companies.................. 4,008 18,727
Accrued taxes............................................. 65,317 2,281
Accrued interest.......................................... 11,333 9,428
Overcollections on rate reduction bonds................... 25,555 12,479
Other..................................................... 12,468 12,685
---------- -----------
173,475 195,549
---------- -----------
Rate Reduction Bonds........................................ 510,841 507,381
---------- -----------
Obligations under Seabrook Power Contracts
and Other Capital Leases.................................. 986 86,111
---------- -----------
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes......................... 359,910 423,050
Accumulated deferred investment tax credits............... 2,680 12,015
Deferred contractual obligations.......................... 56,165 37,712
Accrued pension........................................... 37,933 37,326
Other..................................................... 51,170 46,260
---------- -----------
507,858 556,363
---------- -----------
Capitalization:
Long-Term Debt............................................ 407,285 407,285
---------- -----------
Common Stockholder's Equity:
Common stock, $1 par value - authorized
100,000,000 shares; 301 shares outstanding
in 2002 and 388 shares in 2001......................... - -
Capital surplus, paid in................................ 126,937 165,000
Retained earnings....................................... 194,998 176,419
Accumulated other comprehensive (loss)/income........... (105) 406
---------- -----------
Common Stockholder's Equity............................... 321,830 341,825
---------- -----------
Total Capitalization........................................ 729,115 749,110
---------- -----------
Commitments and Contingencies (Note 6)
Total Liabilities and Capitalization....................... $ 1,922,275 $ 2,094,514
=========== ===========
</Table>
The accompanying notes are an integral part of these consolidated financial
statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
<Table>
<Caption>
- ------------------------------------------------------------------------------------------------------------
For the Years Ended December 31, 2002 2001 2000
- ------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
Operating Revenues...................................... $ 1,046,738 $ 1,171,686 $ 1,291,332
----------- ----------- -----------
Operating Expenses:
Operation -
Fuel, purchased and net interchange power.......... 387,987 713,668 853,563
Other.............................................. 126,506 123,533 122,268
Maintenance........................................... 64,146 56,276 47,429
Depreciation.......................................... 40,941 39,741 43,873
Amortization of regulatory assets, net................ 238,960 65,445 45,874
Taxes other than income taxes......................... 34,226 38,375 42,321
----------- ----------- -----------
Total operating expenses............................ 892,766 1,037,038 1,155,328
----------- ----------- -----------
Operating Income........................................ 153,972 134,648 136,004
Interest Expense:
Interest on long-term debt............................ 16,752 29,308 37,086
Interest on rate reduction bonds...................... 30,499 20,721 -
Other interest........................................ 1,874 915 471
----------- ----------- -----------
Interest expense, net............................... 49,125 50,944 37,557
----------- ----------- -----------
Other (Loss)/Income, Net................................ (1,671) 36,643 14,360
----------- ----------- -----------
Income Before Income Tax Expense........................ 103,176 120,347 112,807
Income Tax Expense...................................... 40,279 38,571 45,256
----------- ----------- -----------
Income Before Extraordinary Loss........................ 62,897 81,776 67,551
Extraordinary loss, net of tax benefit
of $155,783........................................... - - (214,217)
----------- ----------- -----------
Net Income/(Loss)....................................... $ 62,897 $ 81,776 $ (146,666)
=========== =========== ===========
STATEMENTS OF COMPREHENSIVE INCOME
Net Income/(Loss)....................................... $ 62,897 $ 81,776 $ (146,666)
----------- ----------- -----------
Other comprehensive (loss)/income, net of tax:
Unrealized (losses)/gains on securities............... (620) (801) 133
Minimum pension liability adjustments................. 109 - -
----------- ----------- -----------
Comprehensive Income/(Loss)............................. $ 62,386 $ 80,975 $ (146,533)
=========== =========== ===========
</Table>
The accompanying notes are an integral part of these consolidated financial
statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
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........................ $ 1 $424,654 $319,938 $1,074 $745,667
Net loss for 2000............................. (146,666) (146,666)
Cash dividends on preferred stock............. (3,962) (3,962)
Cash dividends on common stock................ (50,000) (50,000)
Capital stock expenses, net................... 255 255
Allocation of benefits - ESOP (b)............. 3,867 3,867
Other comprehensive income.................... 133 133
------- -------- -------- ------ --------
Balance at December 31, 2000...................... 1 424,909 123,177 1,207 549,294
Net income for 2001........................... 81,776 81,776
Cash dividends on preferred stock............. (1,286) (1,286)
Cash dividends on common stock................ (27,000) (27,000)
Repurchase of common stock.................... (1) (259,999) (260,000)
Capital stock expenses, net................... 90 90
Allocation of benefits - ESOP................. (248) (248)
Other comprehensive loss...................... (801) (801)
------- -------- -------- ------ --------
Balance at December 31, 2001...................... - 165,000 176,419 406 341,825
Net income for 2002........................... 62,897 62,897
Cash dividends on common stock................ (45,000) (45,000)
Repurchase of common stock.................... (37,000) (37,000)
Allocation of benefits - ESOP................. (1,063) 682 (381)
Other comprehensive loss...................... (511) (511)
------- -------- -------- ------ --------
Balance at December 31, 2002...................... $ - $126,937 $194,998 $ (105) $321,830
======= ======== ======== ====== ========
</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
$195.0 million of equity at December 31, 2002.
(b) In June 1999, PSNH paid NU parent $10.6 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 PSNH. The amount in 2000 represents the remaining
previously allocated 1993 through 1999 NU parent losses.
The accompanying notes are an integral part of these consolidated financial
statements.
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
<Table>
<Caption>
- --------------------------------------------------------------------------------------------------------------
For the Years Ended December 31, 2002 2001 2000
- --------------------------------------------------------------------------------------------------------------
(Thousands of Dollars)
Operating activities:
Income before extraordinary loss............................... $ 62,897 $ 81,776 $ 67,551
Adjustments to reconcile to net cash flows
provided by operating activities:
Depreciation................................................. 40,941 39,741 43,873
Deferred income taxes and investment tax credits, net........ (79,866) 195,422 (521)
Net amortization/(deferral) of recoverable energy costs...... 9,859 (21,234) (35,860)
Amortization of regulatory assets, net....................... 238,960 65,445 45,874
Net other (uses)/sources of cash............................. (27,703) (62,298) 140,308
Changes in working capital:
Receivables and unbilled revenues, net....................... 2,989 3,212 20,597
Fuel, materials and supplies................................. (7,135) (13,287) 9,316
Accounts payable............................................. 7,583 (48,888) 23,110
Accrued taxes................................................ 63,036 1,624 (33,048)
Other working capital (excludes cash)........................ 14,432 31,095 6,646
--------- --------- ---------
Net cash flows provided by operating activities.................. 325,993 272,608 287,846
--------- --------- ---------
Investing Activities:
Investments in plant:
Electric utility plant....................................... (109,770) (92,626) (69,500)
Nuclear fuel................................................. - (37) (1,153)
--------- --------- ---------
Cash flows used for investments in plant....................... (109,770) (92,663) (70,653)
NU system Money Pool (lending)/borrowing....................... (46,000) 23,000 -
Investments in nuclear decommissioning trusts.................. - (137) (686)
Net proceeds from sale of utility plant........................ - 24,888 -
Buyout of IPP contracts........................................ (5,152) (48,164) -
Other investment activities, net............................... (8,269) (30,906) 2,268
---------- --------- ---------
Net cash flows used in investing activities...................... (169,191) (123,982) (69,071)
---------- --------- ---------
Financing Activities:
Repurchase of common stock..................................... (37,000) (260,000) -
Issuance of long-term debt..................................... - 287,485 -
Issuance of rate reduction bonds............................... 50,000 525,000 -
Retirement of rate reduction bonds............................. (46,540) (17,619) -
Net (decrease)/increase in short-term debt..................... (60,500) 60,500 -
Reacquisitions and retirements of long-term debt............... - (287,485) (109,200)
Reacquisitions and retirements of preferred stock.............. - (24,268) (25,732)
Buydown of capital lease obligation............................ - (497,508) -
Cash dividends on preferred stock.............................. - (1,286) (3,962)
Cash dividends on common stock................................. (45,000) (27,000) (50,000)
Other financing activities, net................................ (13,922) (21,448) (96,922)
--------- --------- ---------
Net cash flows used in financing activities...................... (152,962) (263,629) (285,816)
--------- --------- ---------
Net increase/(decrease) in cash.................................. 3,840 (115,003) (67,041)
Cash - beginning of year......................................... 1,479 116,482 183,523
--------- --------- ---------
Cash - end of year............................................... $ 5,319 $ 1,479 $ 116,482
========= ========= =========
Supplemental Cash Flow Information:
Cash paid during the year for:
Interest, net of amounts capitalized........................... $ 47,506 $ 47,369 $ 38,819
========= ========= =========
Income taxes................................................... $ 56,458 $ 168,021 $ 22,575
========= ========= =========
</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 Public Service Company of New Hampshire
Public Service Company of New Hampshire (PSNH or the company) along with The
Connecticut Light and Power Company (CL&P), and Western Massachusetts
Electric Company (WMECO), 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). PSNH furnishes franchised retail electric
service in New Hampshire and CL&P and WMECO furnish franchised retail
electric service in Connecticut and western Massachusetts. 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.
PSNH 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 PSNH, is subject to the provisions of the 1935 Act.
Arrangements among PSNH, 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. PSNH is subject to further
regulation for rates, accounting and other matters by the FERC and the New
Hampshire Public Utilities Commission (NHPUC).
Several wholly owned subsidiaries of NU provide support services for various
NU's companies, 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 PSNH include the accounts of all
subsidiaries. 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 PSNH.
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 PSNH's rates are intended to recover the cost of removal of
certain utility assets. The amounts recovered do not represent AROs. At
December 31, 2002, PSNH maintained approximately $66.6 million in 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 PSNH 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 PSNH'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 PSNH beginning in the third quarter of
2003. At December 31, 2002, PSNH held equity interests in various VIEs, for
which PSNH was not the primary beneficiary, as PSNH 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
PSNH's consolidated financial statements. For further information regarding
PSNH'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: PSNH owns common stock in four
regional nuclear companies (Yankee Companies). PSNH's ownership interests in
the Yankee Companies at December 31, 2002 and 2001, which are accounted for
on the equity method are 5 percent of the Connecticut Yankee Atomic Power
Company (CYAPC), 7 percent of the Yankee Atomic Electric Company (YAEC), 5
percent of Maine Yankee Atomic Power Company (MYAPC), and 4.3 percent of
Vermont Yankee Nuclear Power Corporation (VYNPC). PSNH'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 million and $8.5
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.
Wyman Unit 4: PSNH has a 3.14 percent ownership interest in Wyman Unit 4, a
632 megawatt oil-fired generating unit. At December 31, 2002 and 2001, plant-
in-service included $6.2 million and $6.1 million, respectively, net of the
accumulated provision for depreciation of $4.7 million and $4.5 million,
respectively.
E. Depreciation
The provision for depreciation is calculated using the straight-line method
based on the estimated remaining useful lives of depreciable utility plant-in-
service, which range primarily from 14 years to 75 years, adjusted for
salvage value and removal costs, as approved by the appropriate regulatory
agency where applicable. Depreciation rates are applied to 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 utility plant-in-
service are equivalent to a composite rate of 3 percent in 2002 and 2001 and
3.2 percent in 2000.
F. Revenues
Revenues are based on rates approved by the state regulatory commissions.
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 NHPUC.
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 PSNH 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."
PSNH'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 believes it is probable that PSNH 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 PSNH's regulatory assets are as follows:
- ---------------------------------------------------------------------
At December 31,
- ---------------------------------------------------------------------
(Millions of Dollars) 2002 2001
- ---------------------------------------------------------------------
Recoverable nuclear costs $ 36.8 $ 40.5
Securitized regulatory assets 505.4 498.2
Income taxes, net 96.5 87.9
Unrecovered contractual obligations 58.7 38.8
Recoverable energy costs, net 241.7 251.6
Other (79.2) 129.8
- ---------------------------------------------------------------------
Total $859.9 $1,046.8
- ---------------------------------------------------------------------
At December 31, 2002, other regulatory assets included a regulatory liability
in the amount of $166.2 million, related primarily to the gain on the sale of
Seabrook.
In 2000, PSNH discontinued the application of SFAS No. 71 for its generation
business and created a regulatory asset for Seabrook over market generation.
In April 2001, PSNH issued rate reduction bonds in the amount of $525
million. PSNH used the majority of this amount to buydown its power
contracts with NAEC. The Seabrook over market generation was securitized at
that time and is reflected in securitized regulatory assets at December 31,
2002 and 2001. On May 22, 2001, the Governor of New Hampshire signed a bill
modifying the state's electric utility industry restructuring laws delaying
the sale of PSNH's fossil and hydroelectric generation assets until at least
February 1, 2004. Since then there has been no regulatory action, and
management currently has no plans to divest these generation assets. As the
NHPUC has allowed and is expected to continue to allow rate recovery of a
return of and on these generation assets, as well as all operating expenses,
PSNH again meets the criteria for the application of SFAS No. 71 for the
generation portion of its business. Accordingly, costs related to the
generation assets, to the extent not currently recovered in rates, are
deferred as Part 3 stranded costs under the "Agreement to Settle PSNH
Restructuring" (Restructuring Settlement). Part 3 stranded costs are
nonsecuritized regulatory assets which must be recovered by a recovery end
date determined in accordance with the Restructuring Settlement or be written
off.
In January 2002, PSNH issued an additional $50 million in rate reduction
bonds and used the proceeds from this issuance to repay short-term debt that
was incurred to buyout a purchased-power contract in December 2001. The
majority of the payments to buyout or buydown these contracts were recorded
as securitized regulatory assets.
PSNH, 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 remaining amounts are recorded as unrecovered
contractual obligations and recovered as stranded costs. During 2002, PSNH
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, PSNH recorded an additional $23.6 million in
deferred contractual obligations and a corresponding increase in the
unrecovered contractual obligations regulatory asset as a result of these
increased costs.
PSNH, 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
(D&D Assessment). 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. PSNH is currently recovering
these costs through rates. No D&D Assessment deferrals were outstanding at
December 31, 2002. At December 31, 2001, PSNH's total D&D Assessment
deferrals were $0.2 million and have been recorded as recoverable energy
costs, net.
In conjunction with the implementation of restructuring under the
Restructuring Settlement on May 1, 2001, PSNH's fuel and purchased-power
adjustment clause (FPPAC) was discontinued. At December 31, 2002 and 2001,
PSNH had $179.6 million and $183.3 million, respectively, of recoverable
energy costs deferred under the FPPAC, including previous deferrals of
purchases from independent power producers. Under the Restructuring
Settlement, the FPPAC deferrals are recovered as a Part 3 stranded cost
through a stranded cost recovery charge. Also included in PSNH's recoverable
energy costs are costs associated with certain contractual purchases from
independent power producers that had previously been included in the FPPAC.
These costs are treated as Part 3 stranded costs and amounted to $62.1
million and $68.1 million at December 31, 2002 and 2001, respectively.
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 $ 73.3 $ 85.8
Regulatory assets:
Securitized contract termination
costs and other 163.0 177.9
Income tax gross-up 36.8 37.8
Other 86.8 121.6
- --------------------------------------------------------------------------
Totals $359.9 $423.1
- --------------------------------------------------------------------------
I. Other (Loss)/Income, Net
The pre-tax components of PSNH's other (loss)/income, net items are as
follows:
- --------------------------------------------------------------------------
For the Years Ended December 31,
- --------------------------------------------------------------------------
(Millions of Dollars) 2002 2001 2000
- --------------------------------------------------------------------------
Gain related to Millstone sale $ - $25.9 $ -
Investment income 1.2 2.3 14.9
Other, net (2.9) 8.4 (0.5)
- --------------------------------------------------------------------------
Totals $(1.7) $36.6 $14.4
- --------------------------------------------------------------------------
2. Seabrook Power Contracts
PSNH and NAEC had entered into two power contracts that previously obligated
PSNH to purchase NAEC's 35.98 percent ownership of the capacity and output of
Seabrook for the term of Seabrook's operating license. NAEC's cost of
service included all of its Seabrook-related costs, including operation and
maintenance (O&M) expenses, fuel expense, income and property tax expense,
depreciation expense, certain overhead and other costs, and a return on its
allowed investment. With the implementation of the Settlement Agreement,
PSNH and NAEC restructured the power contracts and bought down the value of
the Seabrook plant asset, as defined within the Settlement Agreement, to $100
million. On November 1, 2002, NAEC consummated the sale of its investment in
Seabrook. With the sale of NAEC's ownership interest in Seabrook, sales of
capacity and output under the Seabrook Power Contracts ended.
3. Short-Term Debt
Limits: The amount of short-term borrowings that may be incurred by PSNH is
subject to periodic approval by either the SEC under the 1935 Act or by the
NHPUC. PSNH is authorized by the NHPUC to incur short-term borrowings up to
a maximum of $100 million.
Credit Agreement: On November 12, 2002, PSNH, CL&P, WMECO and Yankee Gas
entered into a new unsecured 364-day revolving credit facility for $300
million. This facility replaced a $350 million facility for PSNH, CL&P,
WMECO and Yankee Gas, which expired on November 15, 2002. PSNH 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
no borrowings and $60.5 million, in borrowings, respectively, under these
facilities.
Under the aforementioned credit agreement, PSNH 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 rate on PSNH's notes payable to banks outstanding
on December 31, 2001 was 2.9 percent.
This credit agreement provides that PSNH must comply with certain financial
and nonfinancial covenants as are customarily included in such agreements,
including, but not limited to, consolidated debt ratios and interest coverage
ratios. PSNH currently is and expects to remain in compliance with these
covenants.
Money Pool: Certain subsidiaries of NU, including PSNH, 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, PSNH
had $23 million of lendings to and $23 million of borrowings from the Pool,
respectively. The interest rate on lendings to and borrowings from the Pool
at December 31, 2002 and 2001 was 1.2 percent and 1.5 percent, respectively.
4. Pension Benefits and Postretirement Benefits Other Than Pensions
PSNH participates in a uniform noncontributory defined benefit retirement
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 expense/income,
approximately 35 percent of which was recorded as utility plant, was $0.6
million in expense in 2002, $3.9 million in income in 2001 and $4.3 million
in income in 2000. These amounts exclude pension settlements, curtailments
and net special termination expenses of $1.3 million in 2001.
In conjunction with the Voluntary Separation Program (VSP) that was announced
in December 2000, PSNH recorded $0.5 million in settlement income and $0.3
million in curtailment income in 2001. 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 $2.1 million in 2001. The net total of the settlement
and curtailment income and the special termination benefits expense was $1.3
million of expense, of which $1.2 million was included in operating expenses
and $0.1 million was deferred as a regulatory liability and returned to the
customers.
Postretirement Benefits Other Than Pensions (PBOP): NU's subsidiaries,
including PSNH, 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. NU annually funds postretirement costs through
external trusts with amounts that have been rate-recovered and which also are
tax deductible.
In 2001, PSNH recorded PBOP special termination benefits expense of $0.2
million in connection with the VSP. This amount was recorded as a regulatory
asset and collected through regulated utility rates in 2002.
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 $4.6 million
decrease in PSNH'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 $(227.9) $(211.1) $(65.4) $(52.9)
Service cost (5.8) (5.0) (1.1) (1.1)
Interest cost (16.8) (15.8) (4.6) (4.3)
Plan amendment (1.8) - 4.6 -
Transfers (0.5) 0.1 - -
Actuarial loss (20.6) (9.5) (4.1) (12.4)
Benefits paid - excluding lump sum payments 12.3 11.9 6.9 5.4
Benefits paid - lump sum payments 0.2 3.2 - -
Curtailments and settlements - 0.4 - (0.1)
Special termination benefits - (2.1) - -
- -------------------------------------------------------------------------------------------------
Benefit obligation at end of year $(260.9) $(227.9) $(63.7) $(65.4)
- -------------------------------------------------------------------------------------------------
Change in plan assets
Fair value of plan assets at beginning of year $ 196.6 $ 221.8 $ 28.4 $ 32.4
Actual return on plan assets (21.1) (10.0) (2.5) (2.9)
Employer contribution - - 5.4 4.3
Transfers 0.5 (0.1) - -
Benefits paid - excluding lump sum payments (12.3) (11.9) (6.9) (5.4)
Benefits paid - lump sum payments (0.2) (3.2) - -
- -------------------------------------------------------------------------------------------------
Fair value of plan assets at end of year $ 163.5 $ 196.6 $ 24.4 $ 28.4
- -------------------------------------------------------------------------------------------------
Funded status at December 31 $ (97.4) $ (31.3) $(39.3) $(37.0)
Unrecognized transition obligation 2.3 2.7 24.8 32.2
Unrecognized prior service cost 14.5 14.1 - -
Unrecognized net loss/(gain) 42.7 (22.8) 14.4 4.6
- -------------------------------------------------------------------------------------------------
Accrued benefit cost $ (37.9) $ (37.3) $ (0.1) $ (0.2)
- -------------------------------------------------------------------------------------------------
</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>
- ----------------------------------------------------------------------------------------------------------
At December 31,
- ----------------------------------------------------------------------------------------------------------
Pension Benefits Postretirement Benefits
- ----------------------------------------------------------------------------------------------------------
(Millions of Dollars) 2002 2001 2000 2002 2001 2000
- ----------------------------------------------------------------------------------------------------------
Service cost $ 5.8 $ 5.0 $ 4.8 $ 1.1 $ 1.1 $ 0.9
Interest cost 16.8 15.8 15.0 4.6 4.3 3.9
Expected return on plan assets (20.3) (20.9) (19.7) (2.9) (2.9) (2.6)
Amortization of unrecognized net
transition obligation 0.3 0.3 0.3 2.8 2.9 2.9
Amortization of prior service cost 1.4 1.3 1.3 - - -
Amortization of actuarial gain (3.4) (5.4) (6.0) - - -
Other amortization, net - - - (0.3) (1.1) (0.6)
- ----------------------------------------------------------------------------------------------------------
Net periodic expense/(income) - before
settlements, curtailments and special
termination benefits 0.6 (3.9) (4.3) 5.3 4.3 4.5
- ----------------------------------------------------------------------------------------------------------
Settlement income - (0.5) - - - -
Curtailment income - (0.3) - - - -
Special termination benefits expense - 2.1 - - 0.2 -
- ----------------------------------------------------------------------------------------------------------
Total - settlements, curtailments and special
termination benefits - 1.3 - - 0.2 -
- ----------------------------------------------------------------------------------------------------------
Total - net periodic expense/(income) $ 0.6 $ (2.6) $(4.3) $ 5.3 $ 4.5 $ 4.5
- ----------------------------------------------------------------------------------------------------------
</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 $1.9 $(1.7)
- --------------------------------------------------------------------------
Currently, PSNH'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 post retirement benefit health plan assets is subject
to federal income taxes.
5. Nuclear Generation Asset Divestitures
Seabrook: On November 1, 2002, NAEC consummated the sale of its 35.98
percent ownership interest in Seabrook to a subsidiary of FPL. CL&P, NAEC
and certain other of the joint owners collectively sold 88.2 percent of
Seabrook to FPL. NAEC received approximately $331 million of total cash
proceeds from the sale of Seabrook. A portion of this cash was used to repay
all $90 million of NAEC's outstanding debt, to return a portion of NAEC's
equity to NU and will be used to pay approximately $95 million in taxes. The
remaining proceeds received by NAEC were refunded to PSNH through the
Seabrook Power Contracts. As part of the sale, FPL assumed responsibility
for decommissioning Seabrook.
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, PSNH will continue to buy 4 percent of the plant's
output through March 2012 at a range of fixed prices.
Millstone: On March 31, 2001, CL&P, PSNH and WMECO sold their ownership
interests in Millstone 3 to a subsidiary of Dominion Resources, Inc.
(Dominion). CL&P, PSNH and WMECO sold their ownership interests in Millstone
3 to Dominion along with all of the unaffiliated joint ownership interests in
Millstone 3. PSNH received approximately $25 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.
6. Commitments and Contingencies
A. Restructuring and Rate Matters
In July 2001, the NHPUC opened a docket to review the FPPAC costs incurred
between August 2, 1999, and April 30, 2001. Under the Restructuring
Settlement, FPPAC deferrals are recovered as a Part 3 stranded cost through
the stranded cost recovery charge. On December 31, 2002, the NHPUC issued
its final order allowing recovery of virtually all such costs.
On June 28, 2002, PSNH made its first stranded cost recovery charge
reconciliation filing with the NHPUC for the period May 1, 2001, through
December 31, 2001. This filing reconciles stranded cost revenues against
actual stranded cost charges with any difference being credited against
stranded costs or deferred for future recovery. Included in the stranded
cost charges are the generation costs for the filing period. The generation
costs included in this filing were subject to a prudence review by the NHPUC.
In January 2003, PSNH entered into a settlement agreement with the Office of
Consumer Advocate and the staff of the NHPUC which resolved all outstanding
issues. In conjunction with the settlement agreement, the NHPUC staff
recommended no disallowances resulting from their review of the outages at
PSNH's generating plants. A final order approving the settlement agreement
was issued by the NHPUC in February 2003. The NHPUC order approved PSNH's
reconciliation of stranded costs as outlined within the settlement agreement
and had no impact on PSNH's earnings.
B. Environmental Matters
PSNH 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, PSNH 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 necessarily involve activities
and substances that expose PSNH 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 PSNH'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 PSNH for
its estimated environmental remediation costs amounted to $10.8 million and
$11.4 million, respectively. These amounts include $8.7 million and $9.3
million at December 31, 2002 and 2001, respectively, for remediation of
former manufactured gas plants.
PSNH has a regulatory recovery mechanism for environmental costs.
Accordingly, regulatory assets have been recorded for certain environmental
liabilities.
C. Nuclear Insurance Contingencies
In conjunction with the divestiture of Millstone in 2001 and Seabrook in
2002, NU and PSNH terminated their nuclear insurance related to these plants,
and PSNH has no further exposure for potential assessments related to
Millstone and Seabrook. 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.
D. Long-Term Contractual Arrangements
VYNPC: Previously, under the terms of their agreements, PSNH paid its
ownership (or entitlement) shares of costs, which included depreciation, 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, PSNH will continue to buy approximately 4
percent of the plant's output through March 2012 at a range of fixed prices.
PSNH's cost of purchases under contracts with VYNPC amounted to $6.9 million
in 2002, $6.5 million in 2001, and $6.4 million in 2000.
Electricity Procurement Obligations: PSNH has entered into various
arrangements for the purchase of electricity. The total cost of purchases
under these arrangements amounted to $121.2 million in 2002, $144.4 million
in 2001, and $144.9 million in 2000. These amounts are for independent power
producer contracts and do not include PSNH's short-term power supply
management.
Hydro-Quebec: Along with other New England utilities, PSNH has entered into
an agreement to support transmission and terminal facilities to import
electricity from the Hydro-Quebec system in Canada. PSNH 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 PSNH's
significant long-term contractual arrangements are as follows:
- -------------------------------------------------------------------------------
(Millions of Dollars) 2003 2004 2005 2006 2007
- -------------------------------------------------------------------------------
VYNPC $ 7.7 $ 7.3 $ 6.8 $ 7.1 $ 6.8
Electricity Procurement
Obligations 138.7 142.3 143.8 140.2 63.7
Hydro-Quebec 8.2 8.0 7.8 7.0 6.7
- -------------------------------------------------------------------------------
Totals $154.6 $157.6 $158.4 $154.3 $77.2
- -------------------------------------------------------------------------------
E. Nuclear Decommissioning and Plant Closure Costs
In conjunction with the Millstone, Seabrook 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. PSNH's share of this increase
would total $23.6 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, PSNH's remaining estimated obligations, for
decommissioning for the units owned by CYAPC, YAEC and MYAPC, which have been
shut down were $56.2 million and $37.7 million, respectively.
7. 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 PSNH'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 PSNH'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 $407.3 $421.6
Rate reduction bonds 510.8 565.4
- -------------------------------------------------------------------------------
- -------------------------------------------------------------------------------
At December 31, 2001
- -------------------------------------------------------------------------------
(Millions of Dollars) Carrying Amount Fair Value
- -------------------------------------------------------------------------------
Long-term debt -
Other long-term debt $407.3 $410.0
Rate reduction bonds 507.4 519.4
- -------------------------------------------------------------------------------
Other Financial Instruments: The carrying value of financial instruments
included in current assets and current liabilities approximates their fair
value.
8. Leases
PSNH has entered into lease agreements, some of which are capital leases, for
the use of data processing and office equipment, vehicles and office space.
The provisions of these lease agreements generally provide for renewal
options.
Capital lease rental payments charged to operating expense were $0.4 million
in 2002, $0.7 million in 2001, and $1 million in 2000. Interest included in
capital lease rental payments was $0.3 million in 2002, 2001 and 2000.
Operating lease rental payments charged to expense were $2.6 million in 2002,
$3.9 million in 2001, and $3.5 million in 2000.
Future minimum rental payments, excluding executory costs, such as property
taxes, state use taxes, insurance, and maintenance, under long-term
noncancelable leases, as of December 31, 2002, are as follows:
- --------------------------------------------------------------------------
(Millions of Dollars) Capital Operating
Year Leases Leases
- --------------------------------------------------------------------------
2003 $0.5 $ 4.6
2004 0.4 4.1
2005 0.4 3.4
2006 0.3 3.1
2007 0.2 1.7
After 2007 0.2 3.4
- --------------------------------------------------------------------------
Future minimum lease payments $2.0 $20.3
Less amount representing interest 0.8
- --------------------------------------------------------------------------
Present value of future
minimum lease payments $1.2
- --------------------------------------------------------------------------
9. 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 $0.6 $(0.6) $ -
Minimum pension
liability adjustments (0.2) 0.1 (0.1)
- --------------------------------------------------------------------------
Accumulated other
comprehensive
income/(loss) $0.4 $(0.5) $(0.1)
- --------------------------------------------------------------------------
- --------------------------------------------------------------------------
Current
December 31, Period December 31,
(Millions of Dollars) 2000 Change 2001
- --------------------------------------------------------------------------
Unrealized
gains/(losses)
on securities $1.4 $(0.8) $ 0.6
Minimum pension
liability adjustments (0.2) - (0.2)
- --------------------------------------------------------------------------
Accumulated other
comprehensive
income/(loss) $1.2 $(0.8) $ 0.4
- --------------------------------------------------------------------------
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 $0.3 $0.4 $ -
Minimum pension
liability - - -
adjustments
- --------------------------------------------------------------------------
Accumulated other
comprehensive
income/(loss) $0.3 $0.4 $ -
- --------------------------------------------------------------------------
10. Long-Term Debt
Details of long-term debt outstanding are as follows:
- --------------------------------------------------------------------------
At December 31, 2002 2001
- --------------------------------------------------------------------------
(Millions of Dollars)
Pollution Control Revenue Bonds:
6.00% Tax-Exempt, Series D, due 2021 $ 75.0 $ 75.0
6.00% Tax-Exempt, Series E, due 2021 44.8 44.8
Adjustable Rate, Series A, due 2021 89.3 89.3
Adjustable Rate, Series B, due 2021 89.3 89.3
5.45% Tax-Exempt, Series C, due 2021 108.9 108.9
- --------------------------------------------------------------------------
Long-term debt $407.3 $407.3
- --------------------------------------------------------------------------
There are no cash sinking fund requirements or debt maturities for the years
2003 through 2007. There are annual renewal and replacement fund
requirements equal to 2.25 percent of the average of net depreciable utility
property owned by PSNH in 1992, plus cumulative gross property additions
thereafter. PSNH expects to meet these future fund requirements by
certifying property additions. Any deficiency would need to be satisfied by
the deposit of cash or bonds.
Essentially, all utility plant of PSNH is subject to the liens of the
company's first mortgage bond indenture.
PSNH entered into financing arrangements with the Business Finance Authority
(BFA) of the state of New Hampshire, pursuant to which, the BFA issued five
series of Pollution Control Revenue Bonds (PCRBs) as described above and
loaned the proceeds to PSNH. PSNH's obligation to repay each series of PCRBs
is secured by bond insurance and the first mortgage bonds. Each such series
of first mortgage bonds contains similar terms and provisions as the
applicable series of PCRBs. For financial reporting purposes, these first
mortgage bonds would not be considered outstanding unless PSNH failed to meet
its obligations under the PCRBs.
The average effective interest rates on the variable-rate pollution control
notes was 1.6 percent in 2002 and 2001.
11. 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 $101.1 $(143.5) $41.8
State 19.0 (13.4) 4.0
------ ------- -----
Total current 120.1 (156.9) 45.8
------ ------- -----
Deferred income taxes, net:
Federal (65.0) 197.3 6.7
State (5.5) 13.5 0.8
------ ------- -----
Total deferred (70.5) 210.8 7.5
Investment tax credits, net (9.3) (15.3) (8.0)
- --------------------------------------------------------------------------
Total income tax expense $ 40.3 $ 38.6 $45.3
- --------------------------------------------------------------------------
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 $ 7.7 $ 1.9 $(1.0)
Regulatory deferral (65.3) 13.3 6.9
Regulatory disallowance - 2.3 -
Contractual settlements - 6.7 -
Securitized contract
termination
costs and other (13.5) 177.9 -
Other 0.6 8.7 1.6
- --------------------------------------------------------------------------
Deferred income taxes, net $(70.5) $210.8 $ 7.5
- --------------------------------------------------------------------------
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 $36.1 $42.1 $39.4
Tax effect of differences:
Depreciation 1.9 0.7 0.3
Amortization of
regulatory assets 1.2 6.3 9.9
Investment tax credit
amortization (9.3) (15.3) (8.0)
State income taxes,
net of federal benefit 8.8 0.1 2.9
Other, net 1.6 4.7 0.8
- --------------------------------------------------------------------------
Total income tax expense $40.3 $38.6 $45.3
- --------------------------------------------------------------------------
12. Segment Information
NU is organized between regulated utilities (electric and gas since the
March 1, 2000 acquisition of Yankee) and competitive energy subsidiaries.
PSNH 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 $1,046,738 $1,171,686 $1,291,332 $1,160,589 $1,087,247
Net Income/(Loss) 62,897 81,776 (146,666) 84,209 91,686
Cash Dividends on Common Stock 45,000 27,000 50,000 - -
Total Assets 1,922,275 2,094,514 2,082,296 2,622,433 2,681,595
Rate Reduction Bonds 510,841 507,381 - - -
Long-Term Debt (a) 407,285 407,285 407,285 516,485 516,485
Preferred Stock Subject to Mandatory
Redemption (a) - - 24,268 50,000 75,000
Obligations Under Seabrook Power
Contracts and Other
Capital Leases (a) 1,192 110,275 629,230 726,153 842,223
- --------------------------------------------------------------------------------------------------------
</Table>
- -------------------------------------------------------------------------------
Consolidated Quarterly Financial Data (Unaudited)
- -------------------------------------------------------------------------------
(Thousands of Dollars) Quarter Ended
- -------------------------------------------------------------------------------
2002 March 31 June 30 September 30 December 31
- -------------------------------------------------------------------------------
Operating Revenues $242,381 $248,914 $324,818 $230,625
Operating Income $ 30,750 $ 37,004 $ 40,929 $ 45,289
Net Income $ 11,729 $ 15,231 $ 19,482 $ 16,455
- -------------------------------------------------------------------------------
2001
- -------------------------------------------------------------------------------
Operating Revenues $340,835 $286,799 $299,711 $ 244,341
Operating Income $ 23,222 $ 31,008 $ 45,564 $ 34,854
Net Income $ 28,362 $ 15,517 $ 21,630 $ 16,267
- -------------------------------------------------------------------------------
(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 $1,488,452 14,123 7,208 447,614 1,243
2001 1,499,137 14,953 6,868 439,750 1,241
2000 1,535,343 17,143 6,644 433,937 1,227
1999 2,283,187 12,827 6,665 427,694 1,258
1998 2,302,254 12,576 6,347 421,602 1,265
(a) Amount includes construction work in progress.